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Home My WebLink About175-0321a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 92' (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20"598 13-3/8" J-55 1,992 9-5/8" S-95 & N-80 6,594 7" P-110, S-95 & N-80 9,788 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 10,1993-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6/4/2023 175-032 / 322-631 & 322-406 50-733-20086-01-00 S MGS Unit 09RD739' FSL, 1826' FWL, Sec 35, T8N, R13W, SM, AK 6/21/1975 10,554 / 9,792 Surface 100 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229273.1815 2463911.7284 N/A Middle Ground Shoal / MGS Oil ADL0018746 N/A 1243' FNL, 2544' FEL, Sec 35, T8N, R13W, SM, AK CASING WT. PER FT.GRADE 8/5/1975 CEMENTING RECORD N/A SETTING DEPTH TVD 2467187.7857 TOP HOLE SIZE AMOUNT PULLED N/A 230256.2657 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A N/A SIZE DEPTH SET (MD) 10,200 PACKER SET (MD/TVD) Surf 26 Surf 7,000 2,015Surf Surf 43.5, 53.5 & 40 10,550 Surf 6,474 85 & 95 54.5 598 Surf 7,134 N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 3:13 pm, Jun 23, 2023 Abandoned 6/4/2023 JSB RBDMS JSB 062723 xGDSR-6/29/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.23 14:25:44 - 08'00' Dan Marlowe (1267) Di-09RD Schematic 2023-06-22.doc Updated by JLL 6/22/23 Dillon Platform Di-09RD Dillon Platform Well Di-09RD Last Completed 6/28/85 Oil Well>Injector>>Shut in Tubing String Jewelry Detail # Depth (RKB) Length ID OD Item 1 33’ 1.0’ Cameron Type DC-B Tubing Hanger 2 10,196’ 2.992 3.5Ǝ 3-1/2” 9.3#, N-80, Butt, DSS HTC Coated Tubing 3 10,199’3.5Ǝ 3 ½” DSS HTC Coated Pup 4 10,200’ 1.28’ DSS HTC Coated Seal Locator 5 10,200’ 2.10’6.00Ǝ Baker Model F-1 Packer w/4” Bore 6 10,216’ 15.81’2.985Ǝ Baker Seal Assy 7 10,217’ 0.67’ Mule shoe Sidetrack from Di-09 @ 7134’ MD Date Comments Fish #1 08//85 Perf gun junk @ 10,439’ Fish #2 07/21/75 BHA cemented and KO @ 9,200’MD to drill current hole, TO Cemented BHA 9,606’. Perforations: x Squeezed Perfs from 9,948 – 10,132’, tested to 2,300 psi (6/29/1985) x Open Perfs from 10,267’-10,435’ Casing and Tubing Detail Size Type Wt/ Grade Top Btm CONN / ID Cement / Other 20Ǝ Conductor 85 & 95# Surface 598’Vetco 1,700 sx, Surface 13-3/8Ǝ Surface 54.5#, J-55 Surface 2,015’ 19.7° ST&C / 12.615Ǝ 1,900 sx, 650sx Circ. Out, TOC=Surface 95/8Ǝ Production/Inte rmediate 43.5#, 53.5# S95, 40#, N80 Surface 7,134’8RD / 8.835” 1,250 sxs, Calc TOC = No Cmt above window at 7134’ 7Ǝ Liner 26#, P-110, S-95,N-80 7,000’ 10,550’ 8RD / 6.276Ǝ 900 sxs, tested lap to 1500# would not hold, sqzd w/50 sx and tested to 4000#, tested csg to 3000#/30 min OK , CBL TOC=TOL Tubing 3-1/2Ǝ Production 9.3#, N-80, DSS HTC coated 33’ 10,199’ Butt / 2.992” Tubing String TD =10,550’ PBTD = 10,445’ MAX HOLE ANGLE = 30.1O @ 4,400’MD 1 13-3/8” @ 2,015’ Sqzd Perfs 9,948’-10,132’ LCM pill w/fibers Split in 9-5/8” 6439’ – 6449’ Fish behind 7” casing TOF=9606’ RT-THF: 33’ KB 7” @ 10,550’ 9-5/8” @ 7,134’ G&G OIL TOP 9,903’ MD Tag fill @10,430’ 05/31/02 TOL 7,000’ Perfs 10,267’ – 10,435’ Pkr @ 10,200’ Tbg Punch 10094’ – 10100’ Plugged Tbg Punch 7022’ – 7028’ 3 2 20” @ 598’ Perf gun junk @ 10, 439’, 4 5 6 7 Notes: x 6/19/1985 – Split in Casing at 6439’ (estimated 10ft) shown by impression block, swedged casing w/ 8-3/8” swedge, did not squeeze. x 8/16/2007 – RIH w/tandem gauges to 10,400’ x 7/26-29/2011 – RIH w/2” GR to 10,200’ – no problems. Tubing punch from 10094’ – 10100’, saw immediate pressure drop on Tubing and rise on 9-5/8”. x 8/2011 – Well circulated with 9.8 ppg brine. Pumped LCM pill down tubing but pressured up 5.3 bbls early. Lower tubing punches plugged. Estimated top of LCM pill (with fibers) at 7200’. Tubing punched at 7022’ – 7028’. Freeze protected w/diesel. Well dead. ADL: 18746 PTD: 175-032 Leg 1, Slot 3 API: 50-733-20086-01 2222222222222222222222222222 1 Cement plug #3: Tbg: Surface to ~500’ MD IA: Surface to ~500’ MD OA: Surface to ~500’ MD OOA: Cemented to surface and squeezed from ~500’ MD Cement plug #1 (pumped with CT through retainer & Tbg Punch @ 9,911 – 9,913 WLM) Tbg: 5110’ SLM to 9900’ MD IA: 5000’ MD (Est.)to 9900’ MD Cement plug #2: (pumped through Tbg Punch @ 4709’ ELM) Tbg: 1410’ MD (Est.) to 4700’ MD IA: 1580’ MD (Est.)to 4700’ MD Rig Start Date End Date EL / Cmt Pump 7/30/22 6/20/23 PTSM, Start & warm Eq. Break circulation down tubing out IA good. PJSM, Halliburton cmt unit pump 5 bbls drill water, P/t lines 5000 good. Pump & spot 205 bbls 14PPG class G cmt down coil spotting up IA, 1.2BPM, 4300psi. Un-sting from retainer & lay remaining 30 bbls cmt in tubing holding 450psi back pressure. POOH, t/ ~5000' (EST TOC ) cont. Pump OOH t/4800', CBU x2 clean, POOH laying 44 bbls 9.8 brine in tubing. R/D off Di-09 secure well, turn spool toward Di-05. Move IH to leg 4 from leg 1, finish turn spool to leg 4 lined up to DI-05. Arrange decks, top off T-3 with 9.8 brine. Inject displacement form Cmt job into Di-17. 10/19/22 - Wednesday PTSM, Check, fuel & start Eq. R/D off Di-02, R/U onto Di-09. Install companion flange. P/U & M/U BHA- 2" jet nozzle, 2.8 stabilizer, 2.75stabalizer, circ sub, Hyd, disconnect, jars, check valve, CTC =13.28'. Stab onto well, PT 250/ 4000 good. RIH t/9850' no issues. Pump OOH, t/ surface. Shut in well, break off, L/D BHA, rack IH secure well for night. Mix 9.8 brine for cmt job, m/t return tanks Housekeeping, clean tanks. 10/20/22 - Thursday PJSM, check & start Coil eq. Stack up IH on well. Test BOPE as per Hilcorp & AOGCC, witness was waived by Jim Regg, tested 250/4000 Good. R/D test Eq., P/U retainer assy, stab onto well, test 250/4000 good. RIH t/ 9800', Drop ball, pump on seat, setting retainer @ 9798' set down 4k verify good. Mix & pump 50 bbls mud push. Pump 320- bbls 9.8 brine. Secure well. Mix 9.8 Brine, housekeeping, night watch. 10/21/22 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 09RD 50-733-20086-01-00 175-032 07/30/22 - Saturday Spot Unit. R/U, P/T lubricator 200/3000 good. RIH w/ 1 11/16 tubing punch, Shoot 8 holes f/9911-9913 WLM, drop down log punch good indication. POOH all shots fired. R/D secure well. Rig Start Date End Date EL / Cmt Pump 7/30/22 6/20/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 09RD 50-733-20086-01-00 175-032 11/08/22 - Tuesday R/u circulating eq. Circulated in 8bbls of diesel down IA and 1 bbl down Tbg to freeze protect to 120' below wellhead. R/d circ eq. R/u gauges to monitor pressure over winter. 11/04/22 - Friday R/u AK EL, M/u 2" tbg punch. Stab on lubricator and PT 250-2500psi. RIH tagged TOC 5110', Logged up to 4700', Punched holes in Tbg 4,709'ELM, POOH L/d Tools confirmed gun fired. Secured well SDFN 10/31/22 - Monday R/u AK EL, M/u 1-11/16" CBL, wait on crane to work boat,Stab on well and PT 250-2500psi, RIH w/RCBL and tagged TOC @ 5070', POOH logging, did not see cement. R/d EL 10/23/22 - Sunday R/U W/L with 2 1/4" bailer. PT lubricator t/2500psi good, RIH tag cmt at 5110', Tag witnessed by AOGCC inspector Brian Bixby. POOH r/d W/L for leg move. Secure well. Recover 2 cups cmt interface. AOGCC witnessed By Inspector Brian Bixby, CMIT Tubing x IA Initial 2720 15 min 2590 30 min 2481 re-pressure initial 2730 15 min 2612 30 min 2512 45 min 2420 OA Pre-test 0 Initial 267 15 min 248 30 min 230 45min 217 BBLS in 3.3 BBls out 2.2 Rig Start Date End Date EL / Cmt Pump 7/30/22 6/20/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 09RD 50-733-20086-01-00 175-032 06/02/2023- Friday Travel from heliport to Dillon platform on 09:00 hr flight. Orientation and get familiar with Sundry's on well's MGS Di09, 11 and 13. E-liners and Fox Cementers arrived at 11:00hrs. R/U E-line on Di09, run 3ft gun with 6 shots/ft between collars @ 507'md and 475'md, per's from 500'-503', good indication of firing. Zeroed tool at grating walk around in well room as before. R/D e-line. R/U to circulate down the tubing x IA @.5bpm/0psi, OA=20psi, OOA=0psi, shut in IA and OA pressured up to 450psi (communication verified). Pump down tubing x AI @ 2bpm/150psi, OA=60psi, OOA=0psi. MORU on Di11. 05/28/2023 - Sunday RIH with bailer, jars and weight bar, tag cement @ 1410, POOH with cement sample, sample was soft not hard, Rig up to pre-test CMIT TxIA start psi 2761, @ 15 min 2546 psi, @30 min 2276 psi, test failed, wait on further instructions. 05/29/2023 - Monday CMIT with AOGCC, Sully,down TxIA initial 2803 psi, @ 15 min. 2594 psi @ 30 min 2447 psi, 362 loss test failed, wait on further instructions. 05/25/2023 - Thursday Safety Meeting -E line and pressure testing operations. Rig up E-line and rig up to pressure test intermediates on DI-4, DI- 11, DI-16, DI-9,State inspector requested, sample catcher for cement tag. Heliport received tools needed and both helicopters had mechanical issues and could not fly. State inspector did not make it to platform for witness of Jobs Unload cement return bins from boat. rig up cement line to DI-2 for surface cement. Inject 260 bbl. well fluid from D-9 , RD into DI-17 LS 2100 psi, IA 2600 psi @ 1.4 bpm. 05/23/2023 - Tuesday Rig up cement package to DI-9, prepare for intermediate cement. 05/24/2023 - Wednesday Safety Meeting-Cementing operations. Mix KCL,MIX water for cement, service cementing equipment, mix 10 bbl. spacer unload wireline unit from boat. Pressure test to 1500, Pump down IA, out Tubing 4 bbl. 9.8 brine got returns back @ 2bbl. in, swap to pump down tubing 10 bbl. spacer in IA,(Diffuser 32 bbl.) Pump 41 bbl. cement (82 bbl. in diffuser tank with slurry @ perfs.) pump 243 bbl. total cement away, Diffuser tank @ 261 bbl. Drop ball displace 13 bbl. 9.8 brine final strap 273 bbl. 241 bbl. returns with displacement, 200 bbl. in IA = est. TOC 1580',in IA. Est. TOC of Tubing 1500', close valves on wellhead, wash up lines Final pressure Pump 0 212 bbl. of 14 ppg Class A=4% FCG+.3% FFL, finished with 31 bbl. 14 ppg, class G 4%+.3% Fox Energy.Blen cement. Halibut cement is completely used. Rig Start Date End Date EL / Cmt Pump 7/30/22 6/20/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 09RD 50-733-20086-01-00 175-032 06/20/2023 - Tuesday Verify TOC. OOA-TOC visual at surface, OA-TOC visual at surface, IA-TOC visual at surface, Tbg- visual at surface. 06/04/2023 - Sunday Cement Di-04, r/d from Di-04 and r/u on Di-09, circ. and spot pre-wash on backside of Di-09 tbg,OA and IA. OOA had no injectivity and pressured up. Pre-job, batch up and line up to pmp dwn the tbg and up the OA, start pmp and catch returns instant. Pmp 44bbl @1.5bpm/400psi with -good cement returns seen at surface. Swap over to pmp dwn tbg and up the IA. Pmp 37bbl @1.7bpm/250psi with-good cement returns seen at surface. Swap over to pmp dwn tbg and up the OOA, pmp pressured up @.9bbls to 470psi and dropped to 425psi after 5min. 74bbl cement pmp total by strapping tank (69bbl calculated). Shut in tree and wellhead. Wash up cement unit to cutting boxes. Rest crew. 06/05/2023 - Monday Rigged up on Di-17 and injected 241 BBLS of diesel/FIW at 1.8 BPM with 2100 PSI on 9 5/8" annulus and 2700 PSI on LS. Sim-ops R/D on Di-09 and move all surface equipment to next leg. P&A work done in that leg. Rig up on Di-11 and Di-18. Suck out top 15 BBLS of fluid to check solids level in diffuser tank observing 25-30 BBLS of contaminated cement/solids on the bottom. Added sugar to ensure cement doesn't set up. Rigged up on Di-16 for circ/injection rate in OOA. Rest crew MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:8N Range:13W Meridian:Seward Drilling Rig:N/A Rig Elevation:N/A Total Depth:10554 ft MD Lease No.:ADL 0018746 Operator Rep:Suspend:P&A:XXX Conductor:20"O.D. Shoe@ 598 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2015 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production 9 5/8"O.D. Shoe@ 7134 Feet Csg Cut@ Feet Liner 7"O.D. Shoe@ 10550 Feet Csg Cut@ Feet Tubing:3 1/2"O.D. Tail@ 10119 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Balanced 5110 ft Surface Wireline tag Pre-Test Initial 15 min 30 min 45 min Result Tubing 2803 2594 2441 IA 2803 2594 2441 OA 190 160 145 Remarks: Attachments: Walter Waite Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): F SMGS 9RD cement sample was wet May 27, 2023 Sully Sullivan Well Bore Plug & Abandonment S MSG Unit Dillon 9RD Hilcorp Alaska LLC PTD 1750320; Sundry 322-631 Photos (2) Test Data: Casing Removal: rev. 11-28-18 2023-0527_Plug_Verification_SMGS_Di-9RD_ss              Plug Verification - SMGS Dillon 9RD (PTD 1750320) 5/27/2023 Tubing Cement Sample from Bailer MIT Setup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a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y Anne Prysunka at 10:06 am, Nov 01, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH 6)' <HV IRU WEJ SXQFK RQO\ 1RY %U\DQ 0F/HOODQ 6)' )OXVK 2$ DQG 22$ ZLWK DW OHDVW [ ERWWRPV XS EHIRUH FHPHQWLQJ VXUIDFH SOXJ LI IHDVLEOH 3URYLGH KUV QRWLFH IRU $2*&& RSSRUWXQLW\ WR ZLWQHVV FHPHQW WDJ DQG &0,7 WR SVL %-0 '65*&: Jessie L. Chmielowski Digitally signed by Jessie L. 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3XPS7XELQJ[,$FHPHQWSOXJDVIROORZVJSJ EEOVZHLJKWHGFHPHQWVSDFHU¾JS EEOVSSJ&ODVV*FHPHQWGRZQ7XELQJDQGRXW,$5HFRUG¾SSJ YROXPHRIIOXLGUHFRYHUHG /DXQFKIRDPZLSHUEDOOEHKLQGFHPHQWDQGGLVSODFHGRZQWXELQJZLWKEEOV¾ SSJEULQH 9ROXPHV 7XELQJIURP¶WR¶0'ESI ¶ EEOV¾JS ,$IURP¶WR¶0'ESI ¶ EEOV¾ 7RWDO&HPHQW9ROXPHEEOV 7XELQJIURP¶0'WRVXUIDFHESI ¶ EEOV¾ &0,77[,$WRSVL$2*&&:LWQHVVHGS 3HUIRUDWH7XELQJ´DQG´&DVLQJ#a¶0' EEOVSSJ&ODVV*FHPHQWGRZQ7XELQJDQGRXW22$±LI$ J EEOV),:Z6XUIDFWDQW:DVK 9HULILHG FHPHQW YROXPH EMP 7KLV VHFWLRQ LV WKH PDLQ FKDQJH EMP 3 $6XQGU\5HY :HOO'L5' 37' $WWDFKPHQWV &XUUHQW6FKHPDWLF 3URSRVHG3 $6FKHPDWLF &RQILQLQJ=RQH/RJ &7%23('LDJUDP )OXLG)ORZ'LDJUDP 3 $6XQGU\5HY :HOO'L5' 37' &XUUHQW6FKHPDWLF 3 $6XQGU\5HY :HOO'L5' 37' 3URSRVHG6FKHPDWLF 3 $6XQGU\5HY :HOO'L5' 37' 3 $6XQGU\5HY :HOO'L5' 37' 3 $6XQGU\5HY :HOO'L5' 37' 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, November 14, 2022 3:29 PM To:Harold Soule - (C) Cc:Regg, James B (OGC) Subject:RE: Schlumberger-1 10-20-2022 Attachments:Schlumberger 1 10-20-22 Revised.xlsx Attached is a revised report changing the report date to reflect 10/20/22 based on the start/finish date and the test type to initial. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Harold Soule ‐ (C) <hsoule@hilcorp.com> Sent: Saturday, October 22, 2022 5:20 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com> Subject: Schlumberger‐1 10‐20‐2022 Harold Soule Office 907-776-6681 Dillon Platform Cell 907-227-9400 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. S Middle Ground Shoal Unit Dillon 9RDPTD 1750320 2 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:1 DATE:10/20/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #1750320 Sundry #322-406 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250/4000 Annular:Valves:250/4000 MASP:3540 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.NA Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 0 NA Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 blind/shear P Flow Indicator NA NA #2 Rams 1 pipe/slip P Meth Gas Detector NA NA #3 Rams 0 NA NA H2S Gas Detector NA NA #4 Rams 0 NA NA MS Misc 0 NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2100 P Check Valve 1 2" 1502 P 200 psi Attained (sec)9 P BOP Misc 1 EQ Ports P Full Pressure Attained (sec)26 P Blind Switch Covers:All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA NA No. Valves 5 P ACC Misc 0 NA Manual Chokes 2 P Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 0 NA #1 Rams 15 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 1 P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:3.5 HCR Choke 0 NA Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice No Date/Time 10/18/22 6:52 PM Waived By Test Start Date/Time:10/20/2022 7:30 (date)(time)Witness Test Finish Date/Time:10/20/2022 11:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger Push/pull test on slip rams good, Accumulator precharge 1400psi, 48 hr notice for Platform work not achieved. Albert Tietje Hilcorp Alaska Harold Soule S MGS Unit 09RD Test Pressure (psi): Atietje@slb.com hsoule@hilcorp.com Form 10-424 (Revised 08/2022)2022-1020_BOP_SLB1_SMGS_Dillon-9RD             jbr J. Regg; 11/25/2022 test allowed to proceed w/o 48hr advance notice -- jbr From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - SLB CTU 1 Date:Friday, November 25, 2022 12:25:33 PM Attachments:2022-1020_BOP_SLB1_SMGS_Dillon-9RD.pdf S Middle Ground Shoal Unit 9RD (PTD 1750320) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 hd/KE͗ǆƚĞƌŶĂůƐĞŶĚĞƌ͘KEKdŽƉĞŶůŝŶŬƐŽƌĂƚƚĂĐŚŵĞŶƚƐĨƌŽŵhE<EKtEƐĞŶĚĞƌƐ͘ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP 'RQRWFOLFNOLQNVRURSHQDWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZ WKHFRQWHQWLVVDIH )URP0F/HOODQ%U\DQ-2*& 7R$UDV:RUWKLQJWRQ &F5RE\'DYLG62*&'DYLHV6WHSKHQ)2*& 6XEMHFW5(>(;7(51$/@5(60*637'GHHSFHPHQWUHSRUWV 'DWH:HGQHVGD\1RYHPEHU30 dŚĂŶŬƐ͘ ,ŝůĐŽƌƉŚĂƐǀĞƌďĂůĂƉƉƌŽǀĂůƚŽƉƌŽĐĞĞĚǁŝƚŚƚŚĞƚƵďŝŶŐƉƵŶĐŚĂƚΕϰϳϬϬ͛DŝŶƚŚŝƐǁĞůů͕ƉĞƌƐƵŶĚƌǇ ƐƵďŵŝƚƚĞĚŽŶEŽǀϭ͕ϮϬϮϮ͘ &z/͕ƐƵŶĚƌǇηϯϮϮͲϲϮϭŚĂƐďĞĞŶĂƐƐŝŐŶĞĚƚŽƚŚŝƐǁŽƌŬ͘ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ &ƌŽŵ͗ƌĂƐtŽƌƚŚŝŶŐƚŽŶфƌĂƐ͘tŽƌƚŚŝŶŐƚŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕EŽǀĞŵďĞƌϮ͕ϮϬϮϮϮ͗ϭϯWD dŽ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'ͿфďƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀх ^ƵďũĞĐƚ͗Z͗΀ydZE>΁Z͗^D'^ͲϬϵ;WdϭϳϱͲϬϯϮͿĚĞĞƉĐĞŵĞŶƚƌĞƉŽƌƚƐ ƌǇĂŶ͕ dŚĞƌĞŚĂƐŶŽƚďĞĞŶĂŶǇƌĞͲƉƌĞƐƐƵƌŝǌĂƚŝŽŶ͘KĂŶĚKKŚĂǀĞďĞĞŶϬƉƐŝƉĞƌƚŚĞƉƌĞƐƐƵƌĞƌĞĂĚƐƐĞŶƚ ŝŶůĂƐƚǁĞĞŬĂŶĚǁĞũƵƐƚƌĞͲĐŚĞĐŬĞĚƚŽĚĂǇ͘ŽƚŚĂƌĞĐƵƌƌĞŶƚůǇĂƚϬƉƐŝ͘ ƌĂƐ &ƌŽŵ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'ͿфďƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀх ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕EŽǀĞŵďĞƌϮ͕ϮϬϮϮϭ͗ϯϴWD dŽ͗ƌĂƐtŽƌƚŚŝŶŐƚŽŶфƌĂƐ͘tŽƌƚŚŝŶŐƚŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗΀ydZE>΁Z͗^D'^ͲϬϵ;WdϭϳϱͲϬϯϮͿĚĞĞƉĐĞŵĞŶƚƌĞƉŽƌƚƐ ,ĂƐƚŚĞƌĞďĞĞŶĂŶǇƉƌĞƐƐƵƌĞďƵŝůĚͲƵƉŽŶKŽƌKKŽĨ^D'^ͲϬϵƐŝŶĐĞƚŚĞĚĞĞƉĐĞŵĞŶƚũŽďǁĂƐ ƉƵŵƉĞĚ͍ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ &ƌŽŵ͗DĐ>ĞůůĂŶ͕ƌǇĂŶ:;K'Ϳ ^ĞŶƚ͗tĞĚŶĞƐĚĂǇ͕EŽǀĞŵďĞƌϮ͕ϮϬϮϮϭϮ͗ϮϲWD dŽ͗ƌĂƐtŽƌƚŚŝŶŐƚŽŶфƌĂƐ͘tŽƌƚŚŝŶŐƚŽŶΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗^D'^ͲϬϵ;WdϭϳϱͲϬϯϮͿĚĞĞƉĐĞŵĞŶƚƌĞƉŽƌƚƐ ƌĂƐ͕ ĂŶǇŽƵƐĞŶĚŵĞƚŚĞĚĂŝůǇƌĞƉŽƌƚƐĂŶĚũŽďƐƵŵŵĂƌǇĨŽƌƚŚĞĚĞĞƉĐĞŵĞŶƚƉůƵŐƉƵŵƉĞĚŝŶƚŚŝƐǁĞůů͍ dŚĂŶŬƐ ƌǇĂŶDĐ>ĞůůĂŶ ^ĞŶŝŽƌWĞƚƌŽůĞƵŵŶŐŝŶĞĞƌ ůĂƐŬĂKŝůΘ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ ϯϯϯtϳƚŚǀĞ ŶĐŚŽƌĂŐĞ͕<ϵϵϱϬϭ ƌǇĂŶ͘ŵĐůĞůůĂŶΛĂůĂƐŬĂ͘ŐŽǀ нϭ;ϵϬϳͿϮϱϬͲϵϭϵϯ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tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 35 Township: 8N Range: 13W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10554 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: XXX Conductor: 20" O.D. Shoe@ 598 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2015 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production 9 5/8" O.D. Shoe@ 7134 Feet Csg Cut@ Feet Liner 7" O.D. Shoe@ 10550 Feet Csg Cut@ Feet Tubing: 3 1/2" O.D. Tail@ 10119 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 9900 ft 5110 ft 9.8 ppg Wireline tag Pre-Test Initial 15 min 30 min 45 min Result Tubing 5 2720 2590 2481 IA 5 2720 2590 2481 OA 0 270 250 238 Pre-Test Initial 15 min 30 min 45 min Result Tubing 2481 2730 2612 2512 2420 IA 2481 2730 2612 2512 2420 OA 238 267 248 230 217 Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): F I Long and Short Tubing strings were twinned in with the IA for the test. Pressure loss was -130 psi / -109 psi / -92 psi (below required test pressure). Pressured up for 2nd test; loss was -118 psi / -100 psi/ - 92 psi. I told the company rep that town would make the pass-fail call. 3.3 bbls in, 2.2 bbls returned. September 23, 2022 Brian Bixby Well Bore Plug & Abandonment S MSG UNIT Dillon 9RD Hilcorp Alaska LLC PTD 1750320; Sundry 322-406 none Test Data: Casing Removal: rev. 11-28-18 2022-1023_Plug_Verification_SMGS_Di-9RD_bb 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 ) 7HVWUHVXOWFKDQJHGWR)$,/GRHVQRWPHHW$2*&&FULWHULD IRUSUHVVXUHORVVWUHQGLQJWRZDUG]HURSVLWRWDOSUHVVXUHORVV IRUPLQLQWHUYDOIRUPLQLQWHUYDO- 5HJJ$2*&&,QVSHFWLRQ6XSY 7HVW*UDSK Pressure loss was -130 psi / -109 psi / -92 psi (below gg required test pressure)2nd test; loss was -118 psi / -100 psi/ - 92 psi. James B. Regg Digitally signed by James B. Regg Date: 2022.10.27 16:44:26 -08'00' By Anne Prysunka at 10:23 am, Jul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OIL A1Q) GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W."JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker /Ø'7¥ /'0; \ Dear Mr. Cole: This letter confirms your conversation with COlIunission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the. monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval~ because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under. the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. /~ smc~~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this L2ßay of November, 2004 SCANNED NO\1 2 4 2004 Enel. Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: 7. KB Elevation (ft): 110' KB ABOVE MSL 8. Property Designation: South Middle Ground Shoal 11. Total Depth MD (ft): 10,550' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 10,267-10,435' Packers and SSSV Type: ) STATE OF ALASKA') ALASKA Oil AND GAS CONSERVATION COMMI\:>SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend U Repair well D Pull Tubing D RECE\VED OCT 122004 Perforate U I. ka m\~~~~ijj.~~r{b~á¡cirs'~~.¡U Stimulate DA'~me Extens~9"B'rß(" Other0 Re-enter Suspended w~il ~ "Monitor Frequency 5. Permit to Drj(Number: P. O. Box 196247 Anchorage, Ak. 99519-6247 Development Stratigraphic D D Exploratory 0 Service 0 9. Well Name and Number: Di-09RD 10. Field/Pools(s): Middle Ground Shoall' " Total Depth TVD (ft): 9,785' Length 1,530' 520 psi 2,734 psi 1,130 psi 6,327 psi 3,810 psi 7,240 psi 5,410 psi Tubing MD (ft): Effective Depth MD (ft): 10,445' Plugs (measured): Junk (measured): Size MD TVD Burst Collapse 598' 2,015' 20" 59 15' / 10,898' ,996-10,550' Size: 598' 1,983' 13-3/8" 10,898' 9-5/8" 9,948' 6,469-9,788' Tubing Grade: 3,554' 7" Perforation Depth TVD (ft): 9,526-9,682' 3 1/2" 9.3# N-80 Packers and SSSV MD (ft): 10,217' 10,200' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory' D Development 15. Well Status after proposed work: Oil 0 Gas 0 WAG D GINJ 0 Abandoned WDSPL D D D Service 0 D 0 Plugged WINJ 17. I hereby certify that the foregoing is true and Printed Nam,') .D)';... D. 10le ~ Signature ~a~ ! orrect to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 28-Sep-2004 Phone Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity Other: Subsequent Form Required: Approved by: 3°Y - V-dJk D BOP Test 0 D 0 Mechanical Integrity Test Location Clearance RBDMS BFL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION BY ORDER OF COMMISSIONER THE COMMISSION OR\G\NAL Date: &fT>~ Form 1 O-~evised 12/2003 Submit in Duplicate STATE OF ALASKA ~(')f:'-" .r-. t--: t'" "f- ALASKA OIL AND GAS CONSERVATION COMMISSIÔ»::'l.l ~,= § V !~"'u ~.:.t\...l' REPORT OF SUNDRY WELL OPERATIO~ 262004 1. Operations Abandon D Suspend U Operation Shutdown U Perfo~têUJ. Cè ,:;:' ~~!' W.~iveriW ".,., Other ~ .. . " . I ) 1"1 I ."" Performed: Alter Casing D RepairWell D Plug Perforations D Stimulate D Tirp~ ~xte~sion [j shunH and secure it<,~ILr.:)I'~'$l Change Approved Program D Pull Tubing D Perforate New Pool D Re-enter Suspendeêfell D 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development D Exploratory D 75-32 3. Address: P. O. Box 196247 Stratigraphic D Service 0 6. API Number: Anchorage, Ak. 99519-6247 50-733-20086-01 7. KB Elevation (ft): 9. Well Name and Number: 110' KB ABOVE MSL Di-09RD2 8. Property Designation: 10. Field/Pool(s): South Middle Ground Shoal Middle Ground Shoal/"G" 11. Present Well Condition Summary: Total Depth measured 10,550' feet Plugs (measured) true vertical 9,785' feet Junk (measured) Perf gun @ 10,435' Effective Depth measured 10,445' feet true vertical 9,699' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 598' 20" 598' 598' Surface 2,015' 13-3/8" 2,015' 1,983' Intermediate Production 10,898' 9-5/8" 10,898' 9,948' Liner 3,554' 7" 6,996-10,550' 6,469-9,788' Perforation depth: Measured depth: 10,267-10,435' True Vertical depth: 9,526-9,682' Tubing: (size, grade, and measured depth) 3 1/2" 9.3# N-80 @ 10,217' Packers and SSSV (type and measured depth) BakerMod. 'F1' Packer @ 10,216' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: This well was shutln prior to operation 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service 0 Daily Report of Well Operations 16. Well Status after proposed work: 9i!D.... ..Gas D WAG D GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ìSUndry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer Title Petroleum Engineer /J Ai. §(c'l~\N\NED ~~ð~n 1 Q) 2004 Signature 'A A J ~_:.t,Jln Phone 263-7620 Date 18-Feb-2004 'v v I "'-"'_m Form 1 0-404 Revised ~/2003 III ~ tt821lO0~ nq.\G\N~.L Pertinent ~ SOUTH MJDDLE GROUND SHOAL ADL 18746 WEll NO. 9RD2 HEMLOCK CONGLOMERATE PLATfORM DILLON Spud Oat« ðI1 &11'5 SurfaD8 Lo~ l.8Q 1. Slot 3 7411- FSL. 1823"FW1.. See. 35. T8N, R13W. SJL Sub8ur1oce LocatJon: 10 - 40~ ~ 2nS' FWIoe See. 35. 18M. R13W, s.u. Ð8VQt1on: 1 CKr k8 TD~ 10550" 'NO 8~. P9D: t ~~" 1\'0 "88" Catlng: 2OW, 85 and 9'" Cafng .. at S98' .tth 1700 Þ cement 13 3/8'"1 M.s, 'ta8fng Nt lit 2015. IIfth 1100 - cement 9 ~. 48. 43.5 am! 53.51 Cutnt Ht at 1our.tth 12.50 IX cament 7-. 2~ Uner Hl at 899B-1055G" tdth 900 SIC c.cnent Perfontroø.: lnItJaI Potentra~ ln1UaI Stimulation: hHrVCW Data: CencI Irtervafr. Dsr Intervcû andRaulØ: Log inventory: ~ ~ tØ48-99~"? I"' I 1980-9975" Q- "ao-1~ . 10078-100!lS"? 113100-10111)". G - 2.. 1 (122-t 0132". 10267-10435' G. '3ß .Squeeud 2014 IOPO, 95 ewPD, 41& ua:I) N~ Non. Nan. D1L-SP, SHC-Cft, FDC-GR etU7S Temøenrture-GR VV76 Raclroadfve Tracer ~rwy ~4. t~ CompJettan Record D8pth I. ~ 10" Ooft¡t hanger 34' 2. .3 1/r 8RD and :5 t,7 Buttreu )CO 35" 3. 3 1.12" Buttna and 3 1/2'" DSS HT XC (coated) .38' ~. 3 112- 1.31 N-80 DSS HTC coated tutm¡ 101 Sil" 5. .3 112" OS$" HTC œqbsd pup 1Q19g- B. DSS HTC coated 88CIJ [ocQtðf" 10200. 7, Bakel' Seal aa~ 10216' 8. Uule8hoe . 1021]8 tAa run 6I28/85} BaIc8r Uod81 F- t P J / t 2 3 4 5 l r.2O" as " 94' CSA s9A' t J JIB"' S4J5f CSÞ. 201S. -r 281 Un.. Tcp of a89B' 9948" 10132' 7_- 0281" 0435' fcrßr~ at m t055O" PBD 1044.5' DILLON PLATFORM API # 50-733-20086-01 S. MGS UNIT # 9RD WELL HISTORY Well #9RD DATE COMPLETED EVENT 1975 8/18 Completed as an Oil Well. 1983 12/2 Completed as a Water Injection Well. 3/21 Cement squeeze/reperf 2002 12/07/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di#9RD Hist 12-2-83.doc, last revised 2/18/2004 page 1 Don Sta dual LEG ROOM #1 WEll # 2O"x 13 3/P1' 13 3/P1' x 9 SIPI' 9 S/8. x 3 1/'2' 01-2 1 bbIs 28 bbIs 22 bbls 01-4 4 bbIs IS.5bÞIs 30 bbIs 1)1-9 ~ 01-13 LEG ROOM #2 E 01-18 20bÞIs 01-17 15.5Þb1s 20 Þbf$ 01-16 15 bbIs 20bbIs 01-11 7;4bbIs 01-8 25 bbIs 01-7 ABN-6 r= LEG ROOM #4 0/-5 _.ÖÞÞ/s 18 bbIs ~ 01-3 2 bbls 12 bbls 25 bbIs 20 x 13 5/8 0.1815 300 54.45 3 1/2 tbg. 0.0087 300 18 5/8 x 13 3/8 0.1291 300 38.73 2 7/8 tbg. 0.00579 300 13 3/8 x 9 5/8 . 0.0671 300 20.13 dep. 85Ø 334 9 5/8 x dual 3 1/2 0.0507 300 15.21 355 9 5/8 x dual 2 7/8 0.0571 300 17.13 pump limit 21 psi 9 5/8 x 3 1/2 0.0626 300 18.78 wen #2 wen fI4 wen #9 Wen # 10 Wen #13 Well #7 Well #8 Wen #11 wen #16 Well 17 Well # 18 welln Wen #5 Wen # 12 Wen #14 well #15 WELL BAY # 1 Pumped down tbg.tbg on vac, bled down 9 5/8 x tbg. Pumped 28 bbls. Gas still at surface. Pumped down 20x 135/8 2bbls 100 psi. 20 bbls in 13 3/8. Try to pull eclipse paker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x tbg. Pumped down los, tbg. Retumed up short side 100 bbls. Put 15 bbls In 13 5/8x9 5/8. 4 bbls In 20" ann. Hook up to 20" took approx 1 bbI with charge presS on ann. 13 3.81C ~ 5/8 RumP and bleed 3 bþls i~ an~. 9 5/8xtbg fluid packed with oil. 14.4 bblsln tbg. well 10 is abondoned Fill 20" ann 2 bbls, tbg on vac 7bbls In 13318 x 9 5/8 28 bbls 9 5/8 x tbg. 51.s. 5 s.s.bbls down short side did tbg. And ann same time WELL BAY # 2 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls in tbg.' 20 bbls In 9 5/8 ann.Annulus and tbg. Have oil returns 0 press on well. 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls in Ibg.' 20 bbls in 9 5/8 ann.Annulus and Ibg. Press up to 500 psi. on both tbg. Strings had oil to top no press on tbg. Pumped and bled 7bbls in Ibg. Annulus. When annulus was fluid packed, Oil at surface.5 bbls in 13 5/8 x 9 5/8 press limit. .5 bbls In 20" Well had SOpsi. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of 50 psi..75 of a bbl. Well had l00psi. On 13 3/8x 9 5/8 bleed down to 20psi put ISbbIs of 9.8 fluid, 95/8onn, 20 bbls fluid, tbg,5bbls each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had ISOpsi. On 13 3/8x 9 5/8 bleed down to 20psi put 2Obb1s of 9.8 fluid, 95/8onn, 20 bbls fluid, tbg.5bb1s each, wells 185/8 has25 psi bled off and fluid packed with 9.8 salt took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl s.s. 9518 x tbg, 25 bbls, 13318 x 9518 fluid packed w/12 bbls, 20" ann, 2 bbIs. Ruid packed Pumped 4 bbls 1.5, tbg. 4 bblss.s.R/u to 9 5/8 x 3 1/2 ann. Pumped 15 bbls fluid packed oil to surface. Pumped 4bbls down tbg Is, 4 bbls 5.5. both went on vac. Pumped 15 bbls 95/8 x31/2. WdhSO psi press limit 0 bbls In 13 3/8x 95/8 Fluid packed 20x 133/82 bbls, Auld packed 13 3/8x9 5/812 bbls press up to 200 psi and held. Rig up pump 5 bbls 1.$. 25 bbl 5,5. 8: 9 5/8 x tbg. 8 bbls fluid packed 011 to surface 13 5/8x9 5/8, R/U to 20" ann fluid pack 5 bbls. Press limit 20 psI. .... STATE OF ALASKA '-' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pulltubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: 100' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 190247 ANC, AK. 99519 Service: X South Middle Ground Shoal 4. Location of well at surface 8. Well number 743' FSL, 1818' FWL, Sec. 35-T8N-R13W-SM No. 9RD At top of productive interval 9. Permit number 1342' FSL, 2513' FWL, Sec. 35-T8N-R13W-SM 75-32 At effective depth 10. APl number 1279' FSL, 2536' FWL, Sec. 35-T8N-R13W-SM 50-733-20086-01 At total depth 11. Field/Pool 1260' FSL, 2543' FWL, Sec. 35-T8N-R13W-SM Middle Ground Shoall"G" 12. Present well condition summary Total depth: measured 10,550' feet Plugs (measured) None true vertical 9,785' feet Effective depth: measured 10,445' feet Junk (measured) None true vertical 9,699' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 598' 20" 1700 Sx 598' 598' Surface 2015' 13-318" 1900 Sx 2015' 1983' Intermediate Production 10898' 9-518" 1250 Sx 10898' 9948' Liner 3554' 7" 900 Sx 6996-10550' 6469-9788' Perforation depth: measured ,o,,.,,,, RECEIVED true vertical 9526-9682' Tubing (size, grade, and measured depth) .~.,[~II.:_ 0 '~ 2002 3 112" N-80 ~ 10217' Packers and SSSV (type and measured depth) BakerMod. 'Fl' Packer ~ 10,200' Anl~hora~e 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: Well bore schematic Temperature survey 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that~regoing is true and correct to the best of my knowledge. Signed: _ 1 Title: Water flood Technician Date: 6/25/2002 / - - 1~ /' -- - -- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witneSSplug integrity BOP Test Location clearance IAppr°val N°'~o~-' C~ ~ Mechanical Integrity Test Subsequent form required lO- Original Signed By Cammy Oechsli Taylor Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL June 25, 2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: South Middle Ground Shoals Dillon - 9RD Dear Mr. Maunder: A temperature survey was run on June 1, 2002 which demonstrates that Dillon 9RD (Permit # 1750320 well SMGS 18746-9RD) is in static equilibrium and is not flowing. The attached spreadsheet plots this survey in depth. The plot shows a smoothly varying temperature gradient down to the perforations with no indication of fluid movement. We therefore, conclude that the well is in static equilibrium and presents no danger to any fresh water aquifers or petroleum reservoirs. We have attached the temperature survey and a well schematic. The water flood system on the Dillon Platform has been disassembled and we are not currently planning to resume further injection on this platform. We ask that you approve the 10-403 granting a shut in MIT for this well. RECEIVED JUL 0 1 2002 Sincerely, Jeffery J Dolan Waterflood Technician Cook Inlet Waterflood Management Enclosures Aogcc SMGS Dillon - 9RD Application for SI MIT.doc jjd Dillon 9RD Temperature Survey- June 1 2002 2000 4000 ,,~ ,,~ 6000 8OO0 10000 12000 Temp F. 0 20 40 60 80 100 120 140 160 180 6/25/2002 9:31 AM Jeff Dolan Di9qt.20020601.xls RIH POOH Dillon 9RD Temperature Survey- June 1 2002 2000 4O0O 6000 8000 10000 12000 Temp F. 0 20 40 60 80 100 120 140 160 180 [ ~- ! e m_p_e__ra_~u_re_ \ ~acker @ 1£,200' ~orforations 10,267'Io 10,435' 6/25~2002 9:31 AM Jeff Dolan Di9qt.20020601.xls RIH POOH SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 9RD2 HEMLOCK CONGLOMEF~TE PLATFORM DILLON J Perfo~thmm ggeo-gg~t . ~98o-10o00~ t 0078-1 !~122-10132%; 1~67-1 ~3~, 2014 ~, 95 l~zker k/odad F-1 2015' 7' 2egt t.tn~r gg46' 10132' 10435' 9 5/8" 'K)_, ,I.3.,~ & POD 10445' CSA 10898' MGS DILLON 09RD - I Gas Inj Rate (CD)( Mcf/d )1 - : , ' 2O00 1600 - 1200 800 400 Water Inj Rate (CD) ( bbl/d )1 1 MGS DILLON -- Platform Well Pad MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON MGS--DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS--DILLON -- MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS--DILLON MGS--DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON Alias 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD PTDNO 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 DATE 19831031 19831130 19831231 19840131 19840229 19840331 19840430 19840531 19840630 19840731 19840831 19840930 19841031 19841130 19841231 19850131 19850228 19850331 19850430 19850531 19850630 19850731 19850831 19850930 19851031 19851130 19851231 19860131 19860228 19860331 19860430 19860531 19860630 19860731 19860831 19860930 19861031 19861130 19861231 19870131 Days On Prod Oil Rate (PD) bbl/d Cum Oil Prod Mbbl 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 Days On WaterInj 14 31 29 31 30 31 30 31 31 29 31 30 31 31 24 31 30 29 16 31 28 31 30 31 31 28 31 30 31 30 31 31 25 27 29 26 5 Daily Winj Rate bbl/d 1621 1698 1812 1683 903 1220 1190 955 950 926 1167 1165 1031 866 698 863 570 631 771 1 107 222 273 322 357 373 374 404 349 368 386 442 645 551 478 410 350 C%lm Water Inj Mbbl 0 0 23 75 128 180 207 245 281 310 340 367 403 438 470 496 513 540 557 575 588 588 588 591 598 606 616 627 637 649 661 672 683 695 709 725 740 753 764 766 Page ! MGS DILLON 09RD 100 80 6O 40 20 0 1000 Water Cut Cum Oil Prod Mbb Cum Gas Prod MMcf ) Cum Water Prod Mbbl 10 Oil Rate PD) f %bbl/d Gas Rate fPE f Mcf/d ....... /Vater Rate PD~ ,~5 Gas / Oil Rati¢ f cf/bbt 1 10 0- 10 10-2 975 82 o,~ 84 85 86 MGS DILLON -- Platform Well Pad MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS--DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON -- MGS DILLON MGS-DILLON MGS DILLON MGS--DILLON MGS DILLON -- · MGS DILLON Alias 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD PTDNO 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 DATE 19750831 19750930 19751031 19751130 19751231 19760131 19760229 19760331 19760430 19760531 19760630 19760731 19760831 19760930 19761031 19761130 19761231 19770131 19770228 19770331 19770430 19770531 19770630 19770731 19770831 19770930 19771031 19771130 19771231 19780131 19780228 19780331 19780430 19780531 19780630 19780731 19780831 19780930 19781031 19781130 19781231 19790131 19790228 19790331 19790430 19790531 19790630 19790731 19790831 Days On Prod 10 30 31 30 31 31 29 30 28 29 30 31 31 27 17 * * 31 * 16 30 31 30 * * * * * 30 31 28 31 24 31 30 31 31 30 31 30 31 31 28 31 30 31 30 31 31 Oil Rate (PD) bbl/d 1356 1258 1182 974 435 355 384 270 233 188 252 76 64 0 0 * * 0 * 29 29 30 34 * * * * * 71 85 71 76 77 328 316 295 87 13 15 15 15 15 15 26 20 24 27 76 26 CuB% Oil Prod Mbbl Days On WaterInj Daily Winj Rate bbl/d CURl Water Inj Mbbl 14 * * 0 51 * * 0 88 * * 0 117 * * 0 131 * * 0 142 * * 0 153 * * 0 161 * * 0 167 * * 0 173 * * 0 180 * * 0 183 * * 0 185 * * 0 185 * * 0 185 * * 0 185 * * 0 185 * * 0 185 * * 0 185 * * 0 185 * * 0 186 * * 0 187 * * 0 188 * * 0 188 * * 0 188 * * 0 188 * * 0 188 * * 0 188 * * 0 190 * * 0 193 * * 0 195 * * 0 197 * * 0 199 * * 0 209 * * 0 219 * * 0 228 * * 0 230 * * 0 231 * * 0 231 * * 0 232 * * 0 232 * * 0 233 * * 0 233 * * 0 234 * * 0 235 * * 0 235 * * 0 236 * * 0 238 * * 0 239 * * 0 Page MGS DILLON Platform Well Pad Alias PTDNO DATE Days On Prod Oil Rate (PD) bbl/d Cum Oil Prod Mbbl Days On WaterInj Daily Winj Rate bbl/d Cum Water Inj Mbbl MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS--DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON -- MGS DILLON MGS DILLON MGS DILLON MGS DILLON -- MGS DILLON -- MGS DILLON MGS--DILLON -- MGS DILLON -- MGS DILLON 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 09RD 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 1750320 19790930 19791031 19791130 19791231 19800131 19800229 19800331 19800430 19800531 19800630 19800731 19800831 19800930 19801031 19801130 19801231 19810131 19810228 19810331 19810430 19810531 19810630 19810731 19810831 19810930 19811031 19811130 19811231 19820131 19820228 19820331 19820430 19820531 19820630 19820731 19820831 19820930 19821031 19821130 19821231 19830131 19830228 19830331 19830430 19830531 19830630 19830731 19830831 19830930 30 31 30 31 31 29 31 30 31 30 30 31 30 31 30 31 30 28 31 30 31 30 31 31 30 31 29 31 54 74 5O 56 50 46 0 65 61 59 181 57 67 51 31 35 16 14 17 13 15 24 61 164 60 37 1 1 241 243 245 246 248 249 249 251 253 255 260 262 264 266 267 268 268 269 269 269 270 271 272 278 279 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 281 Page Unocal Corporation 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL ) December 11, 2001 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Re: Dillon Shut-in Injection Well, Di-9RD Dear Tom: We are asking for a time extension until June 31, 2002 on the MIT for Well 9RD while we run temperature survey which is intended to demonstrate the well is in static equilibrium and is not flowing. We ran pressure tests (5/1/01) similar to the tests run in 1997 and obtained similar results. I believe a temperature survey will demonstrate this well's condition while the pressure surveys in 1997 and 2001 do not. I have attached the pressure surveys, a schematic and 10-403 for your approval. The water flood system on the Dillon Platform has been disassembled and we are not currently planning to resume further injection on this platform. Therefore we ask that you approve the 10-403 granting a time extension for this well. Sincerely, Christopher A. Ruff Senior Reservoir Engineer Cook Inlet Waterflood Management RECEIVED DEC 3 1 ZOO1 Alaska Oil & Gas Gaas. C°mmissi°~ \~k-Anchorage\GroupsXAOGCC\Correspondences~ogcc Dillon - Di-9RD Time Extension for Temp Survey.doc car STATE OF ALASKA x~~°.~ ~,~ '~,~ ALASKA OIL AND GAS CONSERVATION COMMISSION "':.,/0~'(,2 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well Plugging: Time extension X Stimulate: Change approved prograrr Pull tubing: Variance: Perforate: Other: 2. Name of Operato 5. Type of well 6. Datum elevation (DF or KB Union Oil company of California {Unocal', Development 100' KB ABOVE MSL feel 3. Address Exploratory 7. Unit or Property name Stratigraphic: PO BOX 190247 ANC, AK. 9951.~ Service: X South Middle Ground Shoal 4. Location of well at surfac{ 8. Well number 743' FSL, 1818' FWL, Sec. 35-TSN-R13W-SIV No. 9RD At top of productive interv~ 9. Permit numbe~, At effective deptl' 10. APl numbel 1279' FSL, 2536' FWL, Sec. 35-T8N-R13W-SN 50-733-20086-01 At total deptl' 11. Field/Poo 1260' FSL, 2543' FWL, Sec. 35-T8N-R13W-SN Middle Ground Shoall"G" 12. Present well condition summar Total depth: measured 10,550' feel Plugs (measured', None true vertica 9,785' feel Effective depth: measured 10,445' feel Junk (measured', None true vertica 9,699' feel Casing Length Size Cementec Measured deptl' True vertical deptl' Structural Conductor 598' 20" 1700 Sx 598' 598' Surface 2015' 13-3/8" 1900 Sx 2015' 1983' Intermediate Production 10898' 9-5/8" 1250 Sx 10898' 9948' Liner 3554' 7" 900 Sx 6996-10550' 6469-9788' Perforation depth measured 10267-10435' true vertica 9526-9682' Tubing (size, grade, and measured deptl' 3 1/2" N-80 @ 10217' Packers and SSSV (type and measured deptl' BakerMod. 'Fl' Packer @ 10,200 13. Attachement.~ Description summary of proposal X Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatio 15. Status of well classification as 16. If proposal well verbally approve( Oil: Gas: Suspended: Name of approver Date approved Service X 17. I hereby certify that th~ for~g~oi~/i~ ~ and correct to the best of my knowled(. Signed: Title: Senior Reservoir En~tinee Date: 12/20/2001 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IAppr°val No'5 Plug integrity.__ BOP Test Location clearance . Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Original $ianed By Commissioner Date. Cammy 0echsli RECEIVED Form 10-403 Rev 06/15/88 DEC 3 1 2001 Alaska Oil & Gas Cons. Commission Anchorage SUBMIT IN TRIPLICATE SOUTH MIDDLE GROUND SHOAL ADL 1874B WELL NO. 9RD. HEMLOCK CONGLOMERATE PLATFORM DILLON L 85 & CSA Pertinent. pot~. Spud Date: PaD: CQ~lflg: 20". 85 =ad O4d Casing M~ at 598' ~ 17~ ~3 ~, 54~ ~g ~ ~ ~5' d~ 1000 $, Oamomn 10" Donut hunger 2. 3 1/2- 8P33 'and 3 1/Z' Buttress XO 35' · 3 I/2" ~B~80,d 3 ,/2" DSS HT XO. (ooatecf) 38' 4. 3 1/2"~~ DSS ~ coabsd tubing 10196' 5, 3 I/2" coabs,~ pup 10100° 8, DSS HT~ eooted m~ [oc~ 10200' 7. Baker baJ ~smnMy 10216' 8. Uuleult~ 1021 ?* run 201 ~* Perforetlone: InWal Potent/al; 2014 BOPO. 9,~ IN/PD, 418 ~ gg48' klTUcd Stbyml~fon: O26? 10435' 0 5/~ 40, 43.~ & (:SA 10898' TI) tDS,~ FBD I044~' MF/Y 1~ '01 06:17PM UNOCAL DILLON P.2 Procedure for M..IT on Dillon DJ-9 Shu~I Injector · , Record daily tubing, casing, and. outer casing pressures for a consecutive three day period, ., Increase casing pressure by 200 psi'. Continue recording d~,'ly tubing, casing, and outer casing pressures for an additionaJ'i consecutive, four-day period. .I , , Date ..... Tubin~ Pressure Casing Pressure · Outer Casin. g Pressure I::.~!=~ 2~6.. _.. . ,~' ' _. · 5'-Z, ~." , .... 30 ,¢ ., ~ ~ ,. ~/o,~ ~ , · -r ,,~____..~, 3--/0 o~ -~ c~ 0'-.,~ ~ , ..... .... 1 ,, .,. · il · . Pr~ssures'R~o~ By: SOUTH MIDDLE GROUND SHOAL ADL 18746 WELL NO. 9RD2 HEMLOCK CONGLOMERATE PLATFORM DILLON Leg t, Sh~t 3 741' ~ J823~JA~ Se~ 3.~ 1t~ E13W. S~ 112 -- 4038' ~ 272S* FdiC, SI~ 3~' ~ ~13W. SM. 10~ WD 178~' 1044~' 'IM) 08o0' I. (:hamonm 10' Donut hunoer 34' 2, 3 ~/2" 8m3 ~d 3 ~/2' ~ X0 ~' 4. 3 1~ g.~ N-~ ~ ~ ~ ~ 10108' 7. h~ ~ ~~ 10216' run 1,3 3~8'* 54~ C:SA 2015' Perfordl(mm Initial Pot~TtTai; gg60--ggT~ ~. G- t · 10122-10132', ~ 2014 BIFD, 9:5 fI~3, 418 tdCFD No~I 0948' 10132' 10267' 0435' (:SA 10808' Procedure for MIT on Shut-in Dillon Injector D-9RD2 1. Record daily tubing, casing, and outer casing pressures for a consecutive three day period. 2. Increase casing pressure 100 psi. Continue recording daily tubing, casing, and outer casing pressures for a consecutive four day period. IWell #: ID-9RD2 Date Tubing Pressure Casing Pressure Outer Casing Pressure 12/15/97 121 27 0 12/16/97 121 27 0 12/17/97 121 27 0 12/18/97 126 100 10 12/19/97 110 70 10 12/20/97 110 40 10 12/21/97 100 10 0 -. · · Pressures Recorded By: ~E0-04-97, THU 17:54 UNOC~ ~SET GftS GRP F~X NO, 9072837874 P, 05/05 Proce, dU,,re for MIT on, Shut-!n Dillo,,n ,In|ecto, r D-gRD2, 1. Record daily tubing, casing, and outer casing pressures for a consecutive three day period. 2. Increase casing pressure 100 psi. Continue recording daily tubing, casing, and outer casing pressures for a consecutive four day period. · Date ,, ,Tubing PressureCasing pressure Outer Casing Pressure I z / z/g.f. 0 7 z~x ..... ,,gr" ~.S~'. _ /z-/r-f T, , ,,, -/~-. q? /.z ! ,,x~. r. ,,, ~ ~ /~. ., ..~-. z~z.. _~ _ /z~. ,. / z.C ., /~ ,.. 4/~ ........ /x-~. /,I,_.o. ,,.~7~ ,/,~ . . /.~_~ ,, //o t/O ,I~ .... t~-~ ~ /0 0 /~' , ~, , ,, .. -. .. ~ . . ,,, , ~ ,, . , , ~ , , ,,.,~ ....... ~ ,,, , ,,. ,, , , , , , . , : _ ., , ,, ,,, ,,. ,, , . , ,, ,, ~ ,~, .... , , , ~, ~ .. ":- ' ~ STATE OF ALASKA "'-" 0 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing ~ Repair well Change approved program __ Operation shutdown Re-enter suspended well __ Plugging __ 'Time extension __ Stimulate ~ Pull tubing m Variance m Pedorate ~ Other .,~_ 2. Namegf QperatoL., iJa unlon ul± Company of Californ 5'~~ent__ 3' Addre~S.o. BOx 196247, Anch. ' AK, 99J5j 19--6~Expl°rat°ry--'graphiCservice~= 4. Location of well at surface Leg iCl, SlOt 3, Platform Dillon 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, SM At top of productive interval 1342' FNL, 2513' FEL, Sec. 35, T8N, R13W, SM At effective depth 1279' FNL, 2536' FEL, Sec. 35, T8N, R13W, SM At total depth 1260' FNL, 2543 FEL, Sec. 35, T8N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 10550 ' feet PlugS(measured) 9785 ' feet 6. Datum elevation (DF or KB) ! no ' p_wn JvJST. feet 7. Unit or Property name SMGS Unit 8. Well number 9RD2 9. Permit number 75-32 10. APl number 50-- 733-20086-01 11. Field/Pool SMGS/Hemlock Effective depth: measured true vertical 10445' feet 9699 ' feet Junk (measured) Casing Length Structural Conductor 556 ' Surface 1979 ' Intermediate 6987' Production 3554' Liner Perforation depth: measured Size Cemented Measureddepth Wueverticaldepth 20" 1700 SX 598' 598' 13-3/8" 1900 SX 2015' 1983' 9-5/8" 1250 sX 6996' 6471' 7" 900 SX 6996'-10550' 6469'-9788' true vertical Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) 10,267'-10,435' 9526'-9682' 3-1/2", N-80 @ 10,217' Baker Model F-1 @ RECEIVED DEC - 9 1991 Alaska Oil & Gas Cons. Commissiot~ Anchorage 10200' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation ! 15. Status of well classification as: October 30, 1991 16. If proposal was verbally approved Oil __ Gas __ Suspended Name of approver Date approved Service 7 17. I hereby certify t,I;~the foregoing is trug. a, nd correct to the best of my knowledge. Signed GA~ $~ BUSH T~tle' REGIONAL DRILLING MANOR ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test_ Subsequent form required 10- /-/.o ~+ Approved by order of the Commissioner FOrm 10-403 Rev 06/15/88 ORIGINAL I {]NJ'lIE C. SMITH J Approval No.¢/ . CCr~issioner Date/~ -/~- ~ SUBMIT IN TRIPLICATE RECEIVED DEC - 9:991 ^~aska Oil & Gas Cons. Commiss:or~ Anchorage SOUTH MIDDLE GROUND SHOAL' ADL 18746 WELL NO. 9RD2 HEMLOCK CONGLOMERATE PLATFORM DILLON Pertinent Dotm 8urfooo Locatfom I]g 1. Slot 3 T4'8' FSL, 1823'FWl. Sea. :SS, TeN, Rt3W. Sad. Subeurfoce LocaUom TD - 4038' ~ 2725' ~ 58~. 35. TeN. R13W, Elevation: 100' KB 1D: I 0,~0' WI;) 9785' PBO: 10440' ~ GECO' Casing: 20., 85 nod 9_41 Coho Nt at 588' _wll~ 1700 ex cement 13 3/B". 54.5J Cooing bet _at 2Q15' with 1900 ex c~moflt O .q~Be, 40* 43,5 and 53.511i Cooing sot ct 10998* with 1250 rx cement 7". 2edit Liner eo~ ct 6996-10550` wlth 900 ax cement PerferotJonm Irdtl(d Potential: MPJol Stimulation: Cored Inte~;ala: DST Intervals and Results: Log bwentor~, · -4: 9948-0953~ 0gT0-ggTob 10078-10088', 10100-10110`, 10122-10132', 10287-10435* · Squeezed '~C:~. 2014 POP[), 95, BWPD. 418 IdCFD (33 . None -Git 5/2/78 car Sutwy Completion Record Depth 1. Oomeron 10' Donut honoar 34' 2, 3 I/2'* Sl~C) and 3 1/2" Buttroso XC) 35' 3 I/2'* But~ and 3 1/2" DSS HT )CO_ (coated) 38' ~ 1/2" g.31JI N-BO DSS HTC ¢ogted tubing 10198' S. 3 I/2" DSS HTC coated pup 10100' 8. DSS HTC coated ~eal Iocator 7. Baker Seal aasombly 10218' 8. Uulohoe 10217' (As mn 8/28/85) Bak~ Uodal F-I 2O" 85 & 04# csA 508" CSk 2015' 7- 28~ One~ T~ a{ 8008* 99411' 10132' I O287' 10436' CSA 10808' TO 10050' PBD 1044~' South Middle Ground Shoal ADL 18746 Well No. 9RD2 Procedure for suspending and freeze protecting well: 1) Bullhead power oil down long string to 100'. The long string will be protected against freezing by power oil at this point. 2) Run hose to 100' inside 9 5/8" casing X tubing annulus. Circulate power oil into 9 5/8" casing X tubing annulus taking returns up hose. The 9 5/8" casing X tubing annulus will be freeze protected at this point. 3) Install blind flanges on all wellhead outlets. 4) Install gauges on the tubing and 9 5/8" casing X tubing annulus. R 'CE'IVED DEC - 9 '199't Alaska 0il & Gas Cons. Commission Anchorage Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 W. G. Smith District Manager February 17, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Chairman File: FEW-O33-WF Report of Sug.d~C-tCei~tions SMGS 1874 .~ll P1 atform~Di 11 on~ Cook.___~ Inlet, A1 as ka /~ti~bched for your records is a State Form 10-404 reporting the resultS of a tubing/packer to annulus integrity test run on the subject well. The test results indicate a positive seal from the tubing to the annulus and Amoco proposes to take no corrective action at this time to repair the casing leak found during the State annulus test of November 25, 1986. Well No. 9RD2 was shut-in indefinitely on January 8, 1987. Immediately prior to shut-in, the well was injecting 449 BWPD at 2000 psi on the tubing. The annulus pressure, while injecting, was 25 psi. When we returned to the well on February 10, 1987, to perform the annulus pressure test, the tubing pressure was 640 psi and the annulus pressure was 0 psi. The negligible change in annulus pressure readings from January 8 to February 10 is a good indication that the tubing/packer to annulus integrity is good. On February 10, we pressured the annulus to 1000 psi and the tubing pressure remainded constant at 640 psi, further substantiating the good tubing/packer to annulus integrity. Although Well No 9RD2 passed this integirty test, Amoco proposes to leave the well shut-in until further notice. Very truly yours, W. G. Smith District Manager Attachments JCB/dds 044/jcb RECEIVED F E B 2 0 1987 Alaska 0il & Gas Cons. Commission Anchorage Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-562-2147 W. G. Smith District Manager February 17, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention- Mr. C. V. Chatterton Chairman File: FEW-O33-WF Report of Sundry Well Operations SMGS 18746 Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached for your records is a State Form 10-404 reporting the results of a tubing/packer to annulus integrity test run on the subject well. The test results indicate a positive seal from the tubing to the annulus and Amoco proposes to take no corrective action at this time to repair the casing leak found during the State annulus test of November 25, 1986. Well No. 9RD2 was shut-in indefinitely on January 8, 1987. Immediately prior to shut-in, the well was injecting 449 BWPD at 2000 psi on the tubing. The annulus pressure, while injecting, was 25 psi. When we returned to the well on February 10, 1987, to perform the annulus pressure test, the tubing pressure was 640 psi and the annulus pressure was 0 psi. The negligible change in annulus pressure readings from January 8 to February 10 is a good indication that the tubing/packer to annulus integrity is good. On February 10, we pressured the annulus to 1000 psi and the tubing pressure remainded constant at 640 psi, further substantiating the good tubing/packer to annulus integrity. Although Well No 9RD2 passed this i ntegirty test, Amoco proposes to leave the well shut-in until further notice. Very truly yours, W. G. Smith District Manager Attachments JCB/dd$ 044/jcb RECEIVED FEB 2 0 1987 Alaska 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK .)IL AND GAS CONSERVATION COMb,. JION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other,~] 2. Name of Operator Amoco Production Company 3. Address P.0. Box 100779, Anchoraqe~ Alaska 99510 4. Location of well at surface 743' FSL, 1818' FWL, Sec. 35, T8N, R13W At top of productive interval 1342' FNL, 2513' FEL, Sec. 35, T8N, R13W At effective depth 1279' FNL, 2536' FEL, Sec. 35, T8N, R13W At total depth 1260" FNL, 2543' FEL, Sec. 35, T8N~ R13W 11. Present well condition summary Total depth: measured 10,550 feet true vertical 9,785 feet Effective depth: measured 10,445 feet true vertical 9,699 feet Plugs (measured) Junk(measured) 5. Datum elevation (DF or KB) 100' (KB) 6. Unit or Property name SMGS 7. Well number 9RD2 8. Approval number 7-69 9. APl number 50-- 733-20086-0[ 10. Pool Hemlock Feet Casing Length Structural Conductor 598 ~ Surface 2015' Intermediate Production 10898 ' Liner 3554' Perforation depth: measured true vertical Size Cemented 20" 1700 sx 13 3/8" 1900' sx Measured depth 598' 2015' True Vertical depth 598' 1983' 9 5/8" 1250 sx 10898' 9948' 7" 900 sx 6,996 ',-10550' 6469'-9788' 10267'~10435' F-1 at 10,200' 9526'-9682' Tubing (size, grade and measured depth) 3½" N-80 @10217' Packers and SSSV (type and measured depth) Baker Model (ECEIVED FEB 2 0 lq~7 12. Stimulation or cement squeeze summary Intervals treated (measured) 0il & Gas Cons. Commission Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Shut-In Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation Shut-In 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Form 10-404 Rev. 124-85 Title District Manager Date Submit in Duplicate SMGS No. 9RD2 - Platform Dillon Annulus Pressure Test 02/10/87 Time Pre-test 10:25 10:30 10:35 10:40 10:55 11:10 11:25 12:25 13:25 -0- 5 Min. 10 Min. 15 Min. 30 Mi n. 45 Min. I Hr. 2 Hrs. 3 Hrs. Tubing Annulus Pressure Pressure 640 ps i -0- 640 ps i 1000 640 psi 950 640 psi 850 640 psi 750 640 psi 660 640 psi 575 640 psi 510 640 psi 370 640 psi 275 Remarks Well Shut-In Pressure applied to annulus and S.I. Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907 -562-2147 District Manager ~ _~ January 23, 1987 V,Q~ ~_. ~,1'~ ,~r. Mr. C. V. Chatterton, Chairman ~ Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaskas 99501 File: FEW-O20-WF Application for Sundr_~~roval SMGS 18746 Well No.~ Platform Dillon, Cook Inlet, Alaska Attached for your approval is a State Form 10-403 for performing a tubing/packer to annulus integrity test on the subject well. The well is presently shut-in and Amoco proposes to maintain the well in a shut-in condition, following the test, until further notice. Very truly yours, W. G. Smith District Manager Attachments JCB/dds 036/jcb R£C£ VEO J A~',I 2 7 19B7 A~aska Oil & Gas Go~s. Gommission Anchorage STATE OF ALASKA ~ ALASC"'~OIL AND GAS CONSERVATION COMi SION APPLICATION FOR SUNDRY APPROVALS 1. Type'of Request: Abandon [] Suspend [] OPeration Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Amoco Production Compan~v 3'Addre~.s0. BOX 100779, Anchorage, Alaska 99510 4. Location of well at surface .~743' FSL, 1818' FWL, Sec. 35, T8N, R13W At top of productive interval 1342' FNL, 2513' FEL, Sec. 35, T8N, R13W At effective depth 1279' FNL, 2536' FEL, Sec. 35, T8N, R13W At total depth 1260' FNL, 2543' FEL, Sec. 35, T8N, R13W 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,550 feet 9,785 feet 10,445 feet 9,699 feet Plugs (measured) 5. Datum elevation (DF or KB) 100' (KB) feet 6. Uni~(~roperty name 7. Well number 9RD2 8. Permit number 75-3? 9. APl number 10. Pool .Hemlock Junk (measured) Casing Length Structural Conductor 598 ' Surface 2,015' Intermediate Production 10,898 ' Liner 3,554' Perforation depth: measured Size 20" 13 3/8" 9 5/8" 7" true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12.Attachments Cemented Measured depth True Vertical depth 1700 sx 598' 598' 1900 sx 2015' 1,983' 1250 sx 10,898' 9,948' 900 sx 6,996-10,550' 6,469-9,788' 10,267-10,435' R E (: E IV E O 9,526- 9,682' 3½" N-80 @10,217' JAN 2 ? 1987 Baker Model F-1 at 10,200' Description summary of proposal ]~ Alaska 0ii & Gas Cons. Commission Anchorage Detailed operations program,~ BOP sketch [] 13. Estimated date for commencing operation February 10, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is trge and correct to the best of my knowledge Signed ~,~,,'~,~'~.~~f_,¢",,~'~,... ~ ~ _ . Title District Manager Commission Use Only Conditions of appr_oval ApProved by Date 01/23/87 Notify commission so representative may witness [] Plug integrity [] BOP Test IApproval No. [] Location clearance ~'~'~"~"~:::'~':':': "~'~ Subsequent Work P,~rted by order ~f ~'~uommms~oner"' " the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Description Summarj/ of Proposal Amoco Production Company proposes to demonstrate good tubing/packer to annulus integrity on SMGS 18746 Well No. 9RD2. Referencing telecon between Lonnie Smith and Jeff Blagg on January 20, 1987 and between Blair Wondzell and Jeff Blagg on January 16 1987, and referencing our correspondence dated January 2, 1987, File: FEW-O01-986.511, it is Amoco's understanding that the AOGCC desires this testing in order to ensure that fluids injected are confined to injection strata. The portion of aquifers beneath Cook Inlet described by a one-quarter (1/4) mile area beyond and lying directly below the Middle Ground Shoal Field are exempt for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c) and no fresh water aquifers are effected by injection activities into Well No. 9RD2. Amoco proposes to demonstrate that there is no communication from the tubing to the annulus by shutting in the injections and monitoring the pressure response of both the tubing and the annulus. If this information is not conclusive, then pressure will be applied to the annulus and the pressure response of the tubing will be measured. If the tests indicate poor tubing/packer to annulus integrity, then Amoco will apply for approval to continue in- jections until corrective action can take place. RECEIVED JAN 2 7 19 7 Alaska 0ii & Gas Cons. ~u..niss~on Anchorage Detailed Operations Program 1. The well is presently shut in. Pressure will be applied to the annulus and the tubing will be monitored. If the tubing does not respond, good tubing/packer to annulus integrity will have been demonstrated. 2. The well will remain shut-in until further notice. W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 22, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File- TJZ-369-WF Dear Sir- Subsequent Notice SMGS 18746 Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached in duplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for repairs made to Well No. 9RD2. Very truly yours, W. G. Smith District Manager Attachments JCB/dds ECEIVED oc'r2 519 l qlaska Oit & Gas Cons. CommJssJor~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL ~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. Amoco Production Company 75-32 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 5o- 733-20086-01 OTHER [] 4. Location of Well Leg 1, Slot 3, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 12. I6. Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name SMGS Unit 10. Well Number 9RD2 11. Field and Pool South Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment r-] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On September 27, 1985, Amoco Production Company: 1. Rigged up a coiled tubing unit and pressure tested. 2. Pump 546 gallons 15 percent HC1 into perforation intervals 10,277 - 10,435 feet. 3. Rigged down coiled tubing. 4. Returned well to injection. RECEIVED ocr 2 198 Alaska 0il & Gas Cons. Commission Anchorage 14.1 hereby,oertify that,., for~g is true and c~prrect to the best of my knowledge. "~" ~' Di strict Manager The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 5, 1985 Hr, C, Vo C~atterton, Chairman Alaska 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Maska 9950:1 File: TJZ-285-WF Dear Sir: Notice of Intent SMGS, 18746 Well No. 9RD2 Platform Dillon, Cook Inlet~ Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, fOr the subject well.· We anticipate performing this proposed work in August, 1985. Very truly yours, W. G. Smith District Manager Attachments · JCB/dds STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTiCeS AND RE;PORTS ON WELLS 1. DRILLING WELL r-I COMPLETED WELL OTHER [] 2. Name of Operator , Amoco Production Company 3, Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well Leg 1, Slot 3, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 7. Permit No. 75-32 8. APl Number 50- 733-200R6-01 9. Unit or Lease Name SMGS Unit 10. Well Number 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Shoal Hemlock I 1 I%l"1 t , AFtl - 1O7A~ i2' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 9RD2 11. Field and Pool South Mi'ddl e Ground NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) ' (Submit in Duplicate) Perforate [] Alter Casing I-1 Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13, Describe 15roposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-'170). In'August, 1985 Amoco Production Company Plans to: 1. Nipple up coiled tubing unit, pressure test. 2. Spot 500 gallon 15 percent HC1 across existing perforation intervals from 10,277 to 10,435 feet. 3. Squeeze acid through perforations. 4. Return well to injection. RECEIVED 41aSka 4~G~.,.s. Crms. Comrni 14. i hereby certify that th_,.~ foregoj,gg is true and correct to the best of my knowledge. Signed_ _ Title District Manao~_r The space below for Commission use D~8!n-~/~5 Conditions of Approval, if any: Approved by. ~pproved Cola~ fleturned By Order of COMMISSIONER the Commission Date sion Form 10-403 Subm,t "Intentions" in Triplicate "" '"" '"'~ ~_.~ ,,c,..~.. ....... o c) ...... ,' ;. Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-272-8471 W. G. Smith District Manager August 5, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: TjZ-284-WF Dear Sir: Subsequent Notice SMGS 18746 Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached in duplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for repairs made recently on SMGS 18746 Well No. 9RD2. Very 'truly yours, W. G. Smith District Manager Attachments JCB/dds RECEIVED AUG 0 .L 5 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND iREPORTS ON WEL L 1. DRILLING WELL [] COMPLETED WELL ]~ 2. Name of Operator 7' Permit N'o Amoco Production Company 75-32 3. Address 8. APl Number P. 0. Box 100779, Anchorage, Alaska 99510 5o- 733-20086-01 4. Location of Well Leg 1, Slot 3, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 6. Lease Designation and Serial No. ADL 18746 12. 9. Unit or Lease Name SMGS Unit 10. Well Number 9RD2 11. Field and Pool South Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other ~/14T' 5 (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Between June 17, 1985 and June 29, 1985, Amoco Production Company: 1. Nippled down tree and nippled up BOP's. Pressure tested to 2,500 psi. 2. Pull tubing. 3. Swaged tight spot at 6,439 feet out to 8 3/8 inches. 4. Milled packer at 9,879 feet. 5. Cement squeezed all perforation intervals between 9,948 feet - 10.,389 feet. Placed 14 sacks Class G cement behind pipe at final · surface squeeze pressure of 3,800 psi. 6. Cleaned well out to 10 4~_42_39 feet. 7; Perforated the intervals 10,287'feet - 10,381 feet - 10,435 feet with 4 JSPF, 90° phasing, 0.3-inch diameter holes, 506 shots total. Set packer at 10,$¢~4_~feet. Stabbed injectiion tubing .string into packer. Inhibited annulus. Nippled up tree and Pressure tested. Returned well to injection. e 9. 10. 11. 14. I hereby certify that the;~oregoir~g is true and correct to //~ J /' ..-~-~ ~'f the best of my knowledge. Signed /~¢/ ~//',~-/¢/~~'~ TitleDistrict Manager The space below for Commission use Dat~8/05/85 Conditions of Approval, if any: By Order of Approved byl COMMISSIONER the Commission Date Form 10-403 Rev. 7-1430 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Hay 13, 1985 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99,510 907-272-8471 File' TJZ-166-WF Nr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir- Notice of Intent MGS 18746 Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached in triplicate is State of Alaska Form 10-403, Sundry Notices and Reports on Wells. We intend to cement squeeze the Upper Hemlock 'G' horizons, deepen the PBTD, and reperforate the Lower Hemlcok 'G' horizons in SMGS Well No. 9RD2. This work is required in order to improve the injection comformace of the well. We anticipate commencing this work during May. Yours very truly, W. G. Smith District Manager AttaChments JCB/dds RECEIVED MAY 1 5 1985 AlaSka 0il & Gas Cons. Commission Anchorage ~ ~ STATE OF ALASKA ~ ALASKA k~lL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLJ~ 2. Name of Operator 7. Permit No. Amoco Production Company 75-32 3. Ad'tress 8. APl Number P. O. Box 100779, Anchorage, Alaska 99510 50- 733-20086-01 OTHER [] 4. Location of Well Leg 1, Slot 3, SMGS Platform Dillon 743' FSL, 1,818' FWL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB 12. I 6 . Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name SMGS Unit 10. Well Number 9RD2 11. Field and Pool South Middle Ground Sh0al Hem]0ck Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate C~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other 0../VkT' .~(-~,~: [~ Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). In May, 1985, Amoco Production Company plans to: 1. Nipple up BOP's and pressure test. 2. Pull tubing. 3. Cement squeeze all perforation intervals between 9,948 - 10,389 feet in the Hemlock "G". 4. Deepen PBTD to 10,545 feet. 5. Perforate the Hemlock "G" intervals 10,380 - 10,450 feet, 10,475 - 10,540 feet with 4JSPF. 6. Set a packer at 10,200 feet. 7. Run a new string of injection tubing and st ing into the packer. 8. Inhibit the annulus with a caustic fluid. 9. Nipple up the tree and pressure test. R E£ E IV E D 10. Return the well to injection. MAY 1 5 1985 Naska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the fj~c,~going is ~ and correct to,the s,.ne The space below for Commission use best of my knowledge. Title Di strict Manager Date 05/13/85 Conditions of Approval, if any: Approved by Approvea C. op~. Returned _._ By Order of COMMISSIONER the Commission Form i 0-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Amoco Production Company (USA) January 24, 1984 File: WEN-O58-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Noti ce South Middle Ground Shoal Unit Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to converting SMGS Unit Well No. 9RD2 to water injection. The well is currently injecting 2,000 BWPD at 3,600 psi. Very truly yours, W. E. Nielsen Superv i sor-i n-Charge Attachments MTS/pbm /-'~'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator Amoco Production Company 3. Address P.O.Box 100779, Anchorage,' Alaska' 99'51'0 4. Location of Well OTHER [] Surface Location- Leg 1, Sl'ot 3, SMGS Platform Dillon Subsurface Location' 4,038' FSL, 2,725" FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) __ 100' KB, MS[ 12. I 6 . Lease Designation and Serial No. ADL 18746 7. Permit No. 75~'32 8. APl Number 5o- 733-2008.6-1 9. Unit or Lease Name SMGS Unit 10. Well Number 9RD~/ < ~% 11. Field a~l Pool South Middle Ground Shoal Hem1 oc k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations .. Stimulate .... ~,~ [] Abandon -' [] ' Stimulation Repair Well "' [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following Work. 1. Determined wellhead pressure, mixed' brine, and killed well. 2. Set back-pres'sure valves, nipp!ed down tree, nippled uo BOP's, and tested to 2,500 psi. Pulled back-pressure valves. 3. Pulled tubing,~.bottomhole assembly, and seal assembly. 4. Retrieved packer set at 9,900 feet. 5. Removed scab liner set at 10,032 feet to 10,175 feet. 6. Cleaned out the wellbore. 7. Set packer at 9,875 feet and ran seal assembly ~and tubing. 8. Placed well on injection. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sign~~'~~~' Title Supervisor=in-Charge The space below for Commission use Conditions of Approval, if any: By Order of Approved by CQMMISSIONER the Commission Muleshoe set at 9,892 feel RECEIVED JAN 2 61984 Alaska 0il & Gas Cons. Cnmp. Anchorage Date ¢"~//.,,2".~-'.,,~ ~ Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 December 1, 983 File: LAD-1115-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent SMGS Unit Well No. 9RD2 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to convert SMGS Unit Well No. 9RD2 from a shut-in production well to water injection. The well has been shut-in since January 1982 due to the production of 100 percent water and the uneconomical situation of repairing the well. A recent reservoir modeling study of the South Middle Ground Shoal Field performed by our Denver Region reservoir engineering staff has predicted a peak production response of 95 BOPD by converting Well No. 9RD2 to injection. We plan on completing this work before the end of this year. Any questions concerning this project can be directed to Mike Schwein in our Anchorage office. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachments MTS/seh DEC 0 5 '~3 Alaska 0il & Gas Cons~ Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL IX-I 2. Name of Operator Amoco Production Company 3. Address P. O. Box 100779, Anchorage, Alaska 99510 4. Location of Well Surface Location' Leg 1, Slot 3, SMGS Platform Dillon Subsurface Location' 4,038' FSL, 2,725' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 100' KB, MSL 6. Lease Designation and Serial No. ADL 18746 7. Permit No. 75-32 8. APl Number 50- 733-20086-1 9. Unit or Lease Name SMGS Unit OTHER [] 12. 10. Well Number 9 Redrill 11. Field and Pool South Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data Pull Tubing NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate E~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to: le e 4. 5. 6. 7. Determine wellhead pressure, mix brine, and kill well. Set back-pressure valves, nipple down tree, nipple up BOP's, and test to 2,500 psi. Pull back-pressure valves. Pull tubing, bottomhole assembly, and seal assembly. Retrieve packer set at 9,900'. Remove scab liner set at 10,032' to 10,175'. Clean out the wellbore. Set packer and run underbalancing disc assembly, seal assembly, and tubing. Drop bar to surge perforations. Place well on injection. OEC05 Alaska Oil & Gas Cons. Anchora,q¢ e Date Signed ,~/.~,~'/"'-~}f/~?/~/~/1'/~ Title District Superintendent The space below for Commission use Conditions of Approval, if any: ORi G~N,~,L SIGNED BY LOttNIE C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Approved by Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow Area Superintendent April 7, 1977 __F~:.~.~, Amoco Production Compan P.O. Box 779 I--'~---~-"i~'l'~--J~41 Anchorage, Alaska 99510 ---:- .......... ,,~__z_, · ..... I ' "' I~i ---Is ~:~'x-:,L ~._ ....... I- ~v ...... --i ..... DRAFT 1 CONFER,: - FILE: File: LAD-280-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001Porcupine Drive Anchorage, Alaska 99510 Dear Sir: Re: Sundry Notice SMGS Unit Well No. 9 Attached is a State of Alaska Form 10-403. Subsequent to perforating SMGS Unit Well No. 9 as described herein. Yours very truly, L. A. Darsow Area Superintendent Attachment ' R£CL:IVE'D APR ,-- 8 1.977 Form 10-403 Submit "Intentions. in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL 1 ! OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, TdN, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RDB 100' Above MSL ].4. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20086-1 6. LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME SMGS Unit 9. WELL NO. 9 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, TdN, R13W, S.M. 12. PERMIT NO. 75--32 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEC~UENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SNOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE~ Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Work Performed December 21, 1976 and March 13, 1977. The following intervals w~ere perforated through tubing and the well was returned to production. 9948-53' 9980-10,000' 9960-75' 10,285-410' 10,415-432' 4JSPF 1-11/16" Tornado Jet Total 182', Density Log, August 6, 1976. Production Prior: Production After: 0-50 BFPD, well pumped off. 35 BOPD, 52 BWPD, 16 MCFD RECE;VED 16. I hereby certify that the foregoing is true and correct TITLE Area Superintendent (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE , DATE Aoril 7. 1977 - DATE See Instructions On Reverse Side Form~ 10-403 REV, 1-10-73 Submit "Intentions" in Triplicate & "Subsequent Reports*' In Duplicate STATE 0~: ALASKA · OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to. drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L I~1 GAS r-] WELLL~ WELI.~ OTHER 2. NAME OF OPERATOR · Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL -At surface Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RDB 100' above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5.- APl NUMERICAL CODE 50-133-20086-1 6. LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME SMGS Unit 9. WELL NO. 9 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. PERMIT NO. 75-32 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF E~ FRACTURE ,TREAT " SHOOT {~[~[:~t~"'~:[~,~. REPAIR WELL (Other) SUBSEQUENT REPORT OF: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* · (Other) _ (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERAT ONS (clearly state all pertinent details, and give pertinent dates, Including estimated date o.f starting any proposed work. Note- Operator proposes to perforate .the following intervals through tubing and return the well to production. 9948-53'' 9960-75' 9980-10,000' 10,285-410' 10,415-432' Verbal approval given bYJ. C. Miller 12/20/76 16, I hereby certify that.the foregoing Is true and correct {TBIs space for State office u,~) Area Superintendent TITLE DATE December 14, 1976 CONDITIONS OF APPROVAL, IF ANY: Petroleum Engineer See Instructions On Reverse Side DATE December 21, 1976 P.O. Box 779 jr AGr' ' 14 ~ ~976 File: GJR-937-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Sundry Notice SMGS Unit Well No. 9 Attached are ~o State of Alaska Forms 10-403. A subsequent notice is attached following the successfUl placement of a scab liner for water shut-off. AIs,,._o attached is our notice of intent to perforat9 additional intervals in the subject w~ll. Yours very truly, George J. Ross Area Superintendent Attachments · -Form 1~-403 REV. 1-10~73 Submit "1 ntention$" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. Ow~LL L [~'-~WELL GAS D OTHER 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' PWL, Section 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RDB +100' MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20086-1 6. LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME SMGS Unit 9. WELL NO. 9 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. PERMIT NO. 75-32 3ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF I~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Work done September 27 through October 14, 1976: 1. Pulled bottom hole assembly and cleaned out to 10,448'. 2. Perforated the intervals 9948-53', 9970-75', 10,410-15' and 10,432- 37' (density log depths) at 4JSPF. 3. Swedged casing 10,075-80'. 4. Isolated perforated zones 10,078-88', 10,100-10' and 10,122-32' with a scab liner and two packers. Packers set at 10,175' and 10,030'. 5. Set production packer at 9900' on 3-1/2" tubing. Ran 2-1/2" Type "E" Kobe pump. 6. Returned well to production. Production Before Workover: Production After Workover: 0 BOPD, 1208 BWPD and 57 MCFD (9-11-76). DEC 1 '7 t976 16. I hereby certify that the foregoing is true and correct Area Superintendent DATE December 14, 1976 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side G. J. Ross Area Superintendent September 9, 1976 File: GJR-689-WF Mr. Hoyle Hamilton, Acting Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Amoco Production Comp; P.O. Box 779 Anchorage, Alaska 99510 i:!~ ..... OL IL ' t :~ c':o~-I'-- .... j .... CONFER: FILE: __ u ! i .... Re: Sundry Notices and Reports on Wells SMGS Unit Well No. 9 Attached is a State'of Alaska Form 10-403. requesting permission to perforate additional zones and perform water'shut-off work utilizing a scab liner at SMGS Unit Well No. 9 as described herein. Your~ very truly, George J. ROss Area Superintendent Attachment f'orm I0 - ¢03 "Intentions" in Triplicate · 'Suio~equent Reports" tn Duplicate sTATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 'SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen ' Use "APP~,ICA'I'ION 'FOR i"Et~IT-A-' '' '/or such 'pt:o~osals.) OIL .~ OAS {--'] WI:LL W~iLL OTHER 2. NAME OF OPERATOR Amoco Pro0u~ion Company 3. ADDIRESS OF OPERATOR P. O. Box 779, _Anchorage, Alaska 4. LOCATION OF A't surface 99510 13. ELEVATIONS W~L Leg 1, Slot 3,' SMGS Platform Dillon, 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M. (Show whether DF, RT, GR, etc. RKB 100' ~bov~ MSL Check Appropriate Box To Indicate N~ture of NOtice, Re 5. APl NUM. F. iHACAL CODE 50-133-20086-1 LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF IN-DIA_N, ALLO'i-i'EE OR TRIBE NA. IVL~ 8. UNIT, FA1R. M OR LEASE NAME SMGS U~i~ 9. W]/:LL NO. 9 10. FLEL, D AND POOL, 01{ WII.,DCAT South Middle Ground Shoal 11. SEC., T., iR., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. PERNIIT NO. ~ort, or Other Data NOTICE OF INTENTION TO : FRACTURE TREAT MULTIPL{ COMPLETE 8HOOT OR ACIDIZE ABANDON* REPAIR %"'LL CHAN0. PLAN, ,Other~ Perforate {UBeIQUENT R~POET OF: FRACTL'R~ TREATMENT ALTER1NO CASINO 8HOOTINO OR ACIDIZINO , ,{ ABANDONM~I~T~ (Other) (NOTE: Report results of multiple completion on Well Completion or Re¢ompletion Report and Log form.) 15 DESCRIBE I'ROPOBED OR COMPLETED 0PERATION8 (Clearly state all pertinent detatl~, and give pertinent dates, Including estimated date of starting an)' proposed work. Proposed Operations: 1. Pull bottom hole assembly and clean out to PBD of 10,454'. Be Perforate the intervals 9948-53'., 9970-75', I0,410-15' and 10,432- 37' (density log depths) with 4JSPF. Isolate the perforated zones 10,078-88', 10,100-10' and 10,122-32' with a scab liner and two packers. 4. Return well to production. Work estimated to begin the week of October 11, 1976. (This space for StiLt~ offil~~ use) APPROVED BY ~ ~ ~ TITLE Area Superintendent DATE September 9, 1976 , TITLE See Instructions On Reverse Side Approved copy Returned Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent May 27, 1976 File: GJR-444-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Sundry Notices and Reports on Wells SMGS Unit Well No. 9 Please find attached a sundry notice indicating our completion of the repair of Well No. 9 on South Middle Ground Shoal Platform Dillon. Yours very truly, Area Superintendent C. '~EOL_~I~ -- ' -C'."E,~e;:~ --I-3 . . . ~'; : · ,~-.~ '"" x,_ L "" E ::, "',F r ..... FILE: Attachment I)IVI[~ON Ot~ 01I. AND GAS F°rm IO-403 REV. I - t0-73 . ' Submit "Intentions" in Trtplio~t~ & "Su~quent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMIYI"EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Us~ "APP-~ .ICATION *FOR ~'EB.~iT-L' 'for such 'p~o~osal$.) ... O,L oas [] WELL WELL OTHSR 2. NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. I,OCATION OF %VF-J~L At su~-face Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 13. ELEVATIONS 14. (Show whether DF, RT, GR, etc. RKB 1~0' above MSL Clmek Appropriate Box To Indicate Nature of I~loti'ce, Re 5. AP1 NUMERICAL CODE 50-133-20086-01 LEASE DESIGNATION AND SERIAL NO. ADL-18746 7. IF IN'DIA2q, ~O'1"~1~ OR TRIBE NAME 8. UNIT, FA~M OR LEASE NAME SMGS Unit 9. WELL NO. 9 10. FIELD A~D POOL, OR WILDCAT South Hiddle Ground Shoal 11. SEC., T., R,, M., (BOT'POM HOLE OBJECTIVE) Sec. 35~ T8N~ R13W, S.M. 12. PERMIT NO. tort, or Other D~ta ' NOTICE .OF INTENTIOlq TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING j~ FRACTURE TREAT MULTIPL~ COMPLETE SHOOT OR ACIDIZE ~ ABANDON~ REPA1R W~LL CHAN0~ PLANS SHOOTINO OB *CIDIZINO ABANDONMENT* (Other) (NOTZ: Report results of multiple completion on Well ~Other) Completion or Recompletion Report and Lo~ form.) 15. DESCRIBE I'RopOsED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. The following prOcedure was used for repairing this well as per verbal approval L. Smith to G. McGregor on April 26, 1976. 1. Ran temperature survey and Gamma Ray log to determine water entry. 2. Perforated the following intervals With 4JSPF: Be 9,980-10,000' 10,078-10,088' 10,100-10,110' 10,122-10,132' 10,285-10,295' 10,306-10,316' 10,349-10,359' Well returned to production. JUN 1976 DIVlt. tON OF OIL ANO OA'~ 16. ! hereb~ ce/eyf~ that the forefoin~ue and eorr~et (This space for 8 ce APPROVED BY CONDITION8 OF APPROVAL, IF ANY: TITLE Area Superintendent DATE TITLE DATE 5-27-76 See Instru~ions On Reverse Side Anchorage, Alaska 99510 G. J. Ross Area Superintendent April 26, 1976 File: GJR-342-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504~ --I-"~ O~OLl ..... I' ~R~T I CONFER: ~[E: - ' ' ~"~ Jill Dear Sir: Re: Sundry Notices and Reports on Wells SMGS Unit Well No. 9 Please find attached a sundry notice indicating our intention to repair Well No. 9 on SoUth Middle Ground Shoal Platform Dillon. The planned work is scheduled to begin the week of April 26, 1976. ¥our's very truly, ~George ~.Ross Area Superintendent Attachment APR 3 ? 1976 DIVISION OF OIL AND GAS Form 10-403 REV. I - 10-73 ~bmtt "Intentions" in Trlplic*t~ ~ ds "Subsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATION COMMrH'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR P'El~fith'l'-L" 'for such 'p~o~osals.) . . WELL WELL OTHER 2. NAMEOFOPER. ATOR Amoco Production Comvanv 3. ADDRESS OF OPERATOR P. O. Box 779, Anchorage, Alaska 99510 4. LOCATION OFW~L Atsurface Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. RKB llO' above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICe OF INTI~NTION ~O: 5. AP1 NU1VLER/CAL CODE 50-133-20086-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18746 ?. IF INDIA.N, A.I. JX)'ri'~:R OR TRIBE NAJVLE 8. UNIT, FARM OR I-,F~SE NAME SMGS Unit 9. WMLL NO. '9 10. FiELD A~D POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. PERMIT NO. ~o~, or Other D~ta SUBaJQCI~NT RBPOIT Or: FRACTURE TREAT MULTIPLJ COMPI.ETE 8H00T OR ACIDIZ~ [ XJ ABANDONe REPAIR V,'~LL CHANO~ PLA~8 ~ Other) I SHOOTINO OR ACIDIZINO , (Other) ALTERINO CASINO ABANDONMENTs (NOTE: Report results of multiple completion on Well C,mpletion or Recompletion Report and Lo~ form.) 15. DESCRIBE I'ROPOSED OR CO.qPLETED OPERATIONS (Clearly state all pertinelit details, and gh'p pertinent dates, Ineludln~ estimated date of startinK any proposed work. The subject well is experiencing abnormal.declines in producing rates. The'following procedure is planned for repairing this well. 1. Run temperature survey and Gamma Ray log to determine water entry. Me Perforate the following intervals with 4JSPF unless temperature survey or Gamma Ray log indicates water entry. o 9,980-10,000' 10'078-10,088' 10,100-10,110' 10,122-10,132' 10,285-10,295' 10,306-10,316' 10,349-10,359' Put the well back on production. APR 2 ? 1970 (Per verbal approval L. Smith to G. McGregor, 4-26-76.) I'hereby C~l~i.f~'-that tha fore,ol~4, _~a (This space for State e use) APPROVED BY . '~L ~ CONDITXONS ANCHO~AO~ TITLE Area Superintendent TITLE See Instructions On Reverse Side DAT~ April 26, 1976 DATE ~{)prOved Copy iReturned // ~L Amoco Production Company P,O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent January 14, 1976 File: GJR-040-WF Mr. John Levorsem 0il and Gas Conservation Committee State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Form P-7 . SMGS Unit Well No. 9 Redrill Please find attached State of Alaska Oil and Gas Conservation Committee Form P-7 for SMGS Unit Well No. 9 Redrill. Yours very truly, Area Superintendent Attachment -, - ...... ,? ORiGiNALi ..Form P~..-; ~-? ' sUBMlT TN .DII'P' STATE OF ALASKA ~S,,,,o,h~. · stru¢ tJon'~ on reverse side~ 5. OIt AND GAS CONSERVATION COMMITTEE 50-133-20086-0~ i i i WELL COMPLETION ~R RECO~PLETION REPORT AND LOG* la. TYPE OF WELL: on, ~ ~ns b. TYPE O~ '"':"' .... SMGS Unit 2. NAME OF OP~ATO~ ~oco Production Company 9. ~V~LNO. 9 Redrill ~ P. 0 Box 779, Anchorage, Alaska 99510 ~0. ~m~~oo~.o, w~caT & LOC~,O~ O~ wZ,~ (a~,O~ ~O~aO- C~ ~"~ ~" ~o~a~,,~ ~"~ ~", S~ ~""'~"~)' - '~ ~ South Middle Ground Shoal A~u~,~, Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' F~, Section 35, T8N, R13W, S.M. o~m~v~) A~ top prod. interval reported below 1440 F~, 2485.71 FEL, ~ 1/4, Sec, 35, T8N, R13W Sec. 35, T8N, R13W, S.M. ~ At totai dep~ , Last gyro survey taken at 10,400' NE 1/4 1296.36' F~L, 2530.66~ FEL, ~ 1/~,~Sec. , , 75-32 13. DA~ S~UDD~ 14. DATE T.D. R~CHED 15. DA~ COMP SUSP OR ABAND. 16. ~EVATIONS IDF, RKB, KT,GR, ~C)* 17. EL~. CASINGHEAD 6~2~-75 8-5-75 Comp. 8-~8-75 ~ ~ 110' ~SL i 59.~' HOW M~Y* ROTARY TOOLS ' '' CABI,E T00I.~ 10.55~~TVD{10,454 ~; 9697 T~ N/A 0-TD ~. PRODUCING ~L(S), OF ~lS COMP~TIO~--TOP, BOSOM, H~E (MD AND ~)' ~. WASsuRvEyD1RECTION~MADE 9220 TVD - 9712 TVD 9938 ~ - 10,456 ~ Lower Kenai Conglomerate .'{ yes ,24. TYPE EI~ECTHIC AND OTtlEt~ LOGS RUN 1ES, Sonic, Dipmeter, Gamma Ray w/ caliper ,, 1'-' 25. ' ""~ASiNG RECORD (Report all strings set in w/Il) I AMOUNT PULLED CASING SIZE ] · 20" 13-3/8" "' 9-5/8" . 85# a 94# ISaH-40{ 598" 126" 11700 sx 54'5// I J-55 I 201.~'' ! 17-1/2"l 19o0 sx 0. 43.5 &: ['S-95 [ 713~' ! originally set at TD w/ [ i I t' LINER RECOIl.I) ' I 27. TUBING SIZE7,,X "TOP(MD) ]EOTTOM (MD) 'SACKS CEMENT'' SC}~EEN (MD) [ SIZE[' 7000' 10,554' [[ 900 Si '''[~[ ',', ]J 3--1/2 il{ DEP'HT SEt(MD) i PACKER SET (MD)9940' ' 9930' 9,985-990o 9,995-10,000 10,078-083 10,105-110 10,123-128 ~. PERORATIONS OPEN TO PRODUCTION - (Interval, size and number) 10,287-292 10,309-314 all with' 10,349-354 4 JSPF 10,410-415 10,432-437 29. ACID, SilOT, F;IAC1 ORE, CEAIENT SQUE."ZZ~:, ETC. DEPTII IN'IEdiVAL (IVID) AMOUNt AND I<IND OF MAIE;~IAL USED 30. PILODUCTION · E FIIRST PP. ODUCTION ! PRODUCTION MEII{OD {FlowlDg, gas liI[. pbllilplrlg--si~e and type of pu~p) [%'EbL S'I'ATUS (Producing or DAT [ . [ omit-in) ~-3/4" I producing 8-19-75 { pumping, 2-1/~" x ' - ~s'r ~-~,uOD 103 , ....... ~l. DISPosITIoN OF GAS (SOld ,,ed/or ]uet, vented, etc.)- ' ! ~J iF t} n ~:' l{ IVY [~ { [ [ [ ' o,',r, aales:fc~'f~ fuel and flare ' ' 8~ LIST history, logs and gyro survey attached ' '"'~ ~ g ' ~"~ c [lf~ that the Ioregoin~ a attached information is complete a3~dx~eorreet,..~ ~ ns determined from ill-available records 33. I here~y ~ ' ~ ~.; /. ,:~..~ , :. ;.., C,~-~ SIGNED /~~= ' ~~ TITLE ~reaS~p~ing,!~ng~, _ DATE December ~=._.1.975 . q .... ; ' ! --- INSTRUCTIONS · " General: This form is designed fo~ submitting a complete and correct well c0mpletio-n report and log on . all types of lan:Js and leases in Alaska. ':'- item: 16: Indicate which eleVation is used as reference (where not otherwise shown) fir depth measu're- merits given in cther spaces on this form and in any attachments. 'i . - · '--:Items 20, and 22:: if this well is ~mpleted for separate production from more than one interval zone ' .' · · . (multiple completion), so state in item 20. and in item 22 show the prc.:tucing inte, r_val, or intervals, toP(s), bottom(s) and name (s) (if any) for-only the interval 'reported in item 30. Submit a separate report · ~(page) On this form, iadequately identified, faf each additional inte, val to be seperately producecl, show- ': ' - ,. ..ing the additional data pertinent to such interval .... _ . '. ' . '. It.m26: "Sacks~ Cement": Attached supplemental records for this well should show the details of. any' mul- · fiple stage ~em~nting and the location of the cementing 'tool. ,. " ... ..- item 28: Submit a separate ·completion report on this. form for each 'interval to be separately produced.: ;: (See ·instruction for items 20'and 22 above).. -. " · · 34. SUMM'A.Ry OF' F'Op,~ATiON "VESTS INCLUDING INTERVAL, T~TEr). PH.F.SSURE DATA ~ ~OV~ OF OIL. G~. ~. G~IC MAR~ " WA~ AND M~D · ........... MEAS. ~ ~UE VERT. D~ .....~ C"~ ~:, ~'~' ~ '~ ~: .,,' ~ .... .. , , '.: · . ~- .~ ,' .. '~ -, - " " '- ~ ? HGS Sand .unit rr:::¢~J '-: c ._ . ., .. ~ '-. 4789 ' ..:7. (~:9.!7 .... :- ~'; ~ .-: Hemlock 9938' 92~0' - .... .~ ~ .-- -. , , --- ~ . ...... ,~ ,~_~ ........ ~. CORE DATA. A~ACll BRIEF D~CRIPI~ONS OF LITHOLOGY. POROSITY, FRACWR~. APP~NT DIPS -. 2 AND D~EC~I) SIIOWS O~ OIL. G~ OR ~VA~. ' " '22 .... . . ~ . .. Z . f .. - ~, . . :. · .. .. -. 2.Z --. &-. . .- , ;, Chronological Well History SMGS Unit Well No. 9 Redrill June 6-11~ 1975: Skidded rig, reversed out Kobe pump, cut the short string tubing at 10,190' and displaced the hole with salt water gel mud. Nippled down tree, nippled up BOP's and tested to 2000 psi. Pulled and laid down short string tubing. Pulled long string out of packer and laid down tubing. Picked up 4'1/2" drillpipe and tripped in to 10,258'. Circulated and set Model "K" retainer at 10,200'. June 12-15, 1975: Cement squeezed production perforations from 10,310- 10,715' with 150 sacks Class G cement to 4000 psi. Perforated 7400- 7401' with 4SPF, set Baker Model "K" retainer at 7250' and squeezed 150 sacks Class G cement to 3500 psi. Perforated 7100-7101' with 4SPF, set packer at 6800' and squeezed with 150 sacks Class G cement to 4000 psi. Ran in with bit and tagged cement at 6790'. Drilled out good, hard cement to 7150' with no cement 7150-7250'. Ran in with mill and milled window 7134-7180'. June 16-18, 197'5: cleaned out to 7226', recovered coal and steel. Tripped in with open-ended drillpipe to 7224' and pumped 200 sacks Class G cement with 1% CaC1. Pulled up 10 stands and reversed out 84 sacks of poor quality cement. Tripped out and waited on cement. Tripped in and drilled good, hard cement 9658-7134'. Tripped out and tested BOP to 3000 psi and Hydril to 1500 psi. June 19 - July 14~ 1975: Tripped in with dynadrill, oriented steering tool and kicked off at 7134'. Directionally drilled and surveyed 7134- 10,550'. Ran DIL, Sonic, Density and Dipmeter logs to 10,554'. Tripped in with bit and stuck pipe at 10,515'. July 15-18~ 1975: Worked pipe, ran free-point and backed off at 9448' with free-point at 9488'. Proceeded to jar and work stuck pipe, ran free-point and backed off at 9293'. July 19-22~ 1975: Tripped in.with 8-1/2" wash pipe and washed over top five drill collars. 'Backed off at 9451' and recovered five drill collars. Tripped in with wash pipe and washed over fish from 9451-9626'. Recovered 5 joints of drillpipe by backing off at 9606'. Washed over fish 9606- 9726' but unable to recover any more pipe. July 23-25~ 1975: Screwed into fish, ran spud tool to 10,476' and per- forated 10,473-10,475' at 4SPF. Established circulation of 9 BPM at 1500 psi. Displaced 250 sacks Class G cement with 0.1 gallon per sack D-81 around fish. Backed off fish ~nd circulated hole clean. After -2- WOC, screwed back into fish and pressured to 2900 psi and pressure held. Ran spud tool and top'of the cement in the fish at 9611' and appeared fish was cemented. Spot 290 sacks Class G cement with 0.1 gallon per sack D-81, 0.23 gallon per sack D-80, 20% frac'sand with slurry density of 17.1 ppg at the top of the fish. Pulled drillpipe to 9100' and circulated out trace of cement contaminated mud. July 26-29~ 1975: Drilled cement stringers 9110-9160' and hard cement 9190-9200'. Tripped for dynadrill and kicked off at 9200'. Drilled to 9239' and unable to drill out of old hole. Run dynadrill and kicked off at 9336'. July 30-31,1975: Directionally drilled and surveyed 9336-9588'. August 1-6~ 1975: Directionally drilled and surveyed 9588-10,550'. Ran DIL-IES, Sonic and Density logs to 10,550' TD.. August 7-11~ 1975: Ran 83 joints of 7", 26# casing from 7000-10,550'. Cemented casing with 600 sacks Class G cement with 2% prehydrated gel and tailed in with 300 sacks Class G cement. Released from liner and circulated cement. Drilled out cement to 10,455' and tested liner to 1500 psi. Displaced hole with injection water. Ran gyro survey, Gamma Ray cement bond log and collar locator log. Displaced hole with power oil. August 12-13~. 1975: Ran and set Baker F-1 packer at 9930'. Ran seal assembly, 2-1/2" Kobe Type "E" BHA and 3-1/2" tubing to 9905'. Ran dummy pump to gauge tubing. Pulled dummy pump and detected fluid influx. Reversed out power oil and water slug. Pressure tested to 2000 psi and bled back to 1400 psi in 15 minutes. Pulled Kobe BHA and stung into packer at 9930'. Pressured up tubing to 2500 psi and annulus to 1000 psi. Tubing pressure 2400 psi in 45 minutes and casing pressure 680 psi in 45 minutes. Pulled seal assembly and set 7" packer at 7060', pressured tubing to 2500 psi, held okay. Pressured annulus to 1100 psi and bled back to 800 psi in 10 minutes. Reset packer at 7028' and pressured tubing to 3500 psi, held okay. Pressured casing to 1100 psi and bled off slowly. Pulled 7" packer'and set 9-5/8" packer at 6990'. Pressured annulus to 1000 psi, held okay. Pressured tubing to 3500 psi and bled back to 2000 psi. Established injection rate at 2-1/4 BPM at 3500 psi; 1-1/4 BPM at 3000 psi. Shut in tubing and'pressure bled to 1950 psi in 15 minutes. Bled off tubing and casing and tubing flowed small stream. August 14-17~ 1975: Pulled tubing, ran in with drillpipe and set 9-5/8" packer at 6828'. Established injection, spotted 50 sacks Class G cement and squeezed to 4000 .psi. Drilled out cement and pressure tested casing - 3- to 3000 psi for 30 minutes, held okay. Reran seal assembly, Kobe cavity, and 3-1/2" tubing. Displaced well with power oil and landed tubing. Nippled down BOP's and nippled up tree. AuguSt 18~ 1975:' Rigged up Dresser-Atlas and tagged bottom at 10,392'. Perforated the following intervals at 4SPF: '9,985- 9,990' 9,995-10,000' 10,078-10,083' 10,105-10,110' 10,123-10,128' 10,287-10,292' 10,309-10,314' 10,349-10,354' Ran standing Valve and Kobe Type "E" pump. TD 10,550', PBD 10,392'. 24-hour test results: 2014 BOPD, 95 BPWD, 207 MCFD, 103 GOR. SPERRY. SUN DIRECTIONAL SURVEY REPORT FOR AMOCO PRODUCTION COMPANY TYPE OF SURVEY: GYROSCOPIC MULTISHOT SURVEY DEPTH: FROM Surface _ir~. TO LEASE:, SMGS 35-SN-13W FIELD: , SQ,UTH MIDDLE GROUND SHOAL COUNTY/PARISH KENAI DATE OF SURVEY. 8-10-75 lOB NO. 10,~00 .WELL NO. STATF ALASKA su~-16Ol6 OFFICE: Anchorage 274-6696 AHOCO PRODUCTZON COMPANY SMGS NUMBER 9 SOUTH'"~-DD'EE--~ROUND-$-HOAL ALASKA SPERRY-SUN WEL ]SURVEYTNG COMPANY .COMPUTATION DATE 7AUGUST -;L.5-~' ..... i975 DATE OF SURVEY AU6UST 10, 19'~5 ' SURWEL GYROSCOPIC MULTISHOT SUR'~E1 dOB NUMBER SU~-1601~ KELLY BUSHING ELEV. = llO.O0 FT. TRUE MEASURED VERTICAL --'DEPTH DEPTH ~$UB-SEA COURSE COURSE DOG-LEG TOTAL V~RTICAL [NCLINATION. DIRECTION SEVERITY RECTANGULAR COORDINATES · DEPTH bEG -MIN' DEGREES ......... :'~'DEG~I-O-b' ..... NORTH/SOUTH EAST/~EST VERTICAL SECTIOf~ 0 0,00 '-110,00 293 ' 29~,99 182,9~ 555 .55~,98 ~7" '~6,97 .... --336;97 5~9 5~,97 ~28,97 615 700 8OO 9O0 1000 1100 1200 1 oo 1~00 61~,96 '799,78 " 8~S.50 '99~,"1~ 109~o76 1596,56 50~,96 689.78 789,50 988,76 -1088,25 1286,~6 0 0 S O, 0 E 0 20 $- 11. 0 N 0.I0 1.0~ i 15 S ~5, 0 E 1,68 1,77 O 55 S 57. 0 E 0,10 5,2q 0 25 ..... N_..89, .... o .E ..........0._,~.6 ............. ~.,~6 2 15 N 70, 0 E 2,19 2,87 ~ ~5 N 66, 0 E 1,51 0.87 O,O0 0,00 0,00 0,00 0.~2 E .............. 2,2~ E -2,~9 2 ................... 2.5 2 ~,55 E ~ ~5 N ~8. 0 E ........ 1,65 ~.22 N 15.61E 7,.~1 5 ..... O ....... N--"35.-O'-E ...... Sji'~ 9.56 'N ................ --E-~-,~9--~ ................. i5.05 5 0 N 30, 0 E 0,~3 16,91 N 85,87 6 ~5 N 20, 0 E 2,02 26,20 N. ~0,06 E 8 o N o E ........... i.5 ............ ......... ............ ~ ~0 N 1~. 0 E 0.50 52..9 N S6.~6 E 1500 1600 .... 1700 1800 ~90'0 1975 2000 ............ 2100 2200 2~00 ~OC 2500 2600 ........... 2700 2800 2~0 1995,08 1~85,08 9 ~5 N 17, 0 E 1,~0 67,79 N 91,00 £ 76,~7 '159~';31 -"---:1~83;31 ....... 11 ...... ~5 ....... N 25, O'E ..... 2,28 ...........85,2G ;,i ~7"~.5--~ ......... 95.05 1690,89 1580,89 1~ ~0 N 25, 0 E 1,80 105.21 N 56,~6 5 116.68 1787,63 1677.63 15 ~5 N 25, 0 E 2,25 128.09 ~8-8~-;~7 ~773','37 17 .... ~5 ....... h 2~. 0 E .............. a;i7 ........ i5~.85 r~ ......... --7'~;'9f'"~ ....... i~.9~ 195~.59 i8~,59 18 45 N29, 0 E 1.39 17~,~8 N 91.1~ E It )67 1978,20 i868.20 19 ~0 N 50,12 E 3,95 181,6~ N 95,19 E 200,&6 2072,-0~'-~196'2,'0~ ..... 20"-~6 ...... N 30. 5 E ............. l,lO ' 211.5~-~ .... ['i'2,51--E 25~.39 2165..56 2055,56 20 ~1 N .29.88 E 0.11 2~2.20 N 130,18 E 258.7~ 2259.08 21~9.08 20 ~9 N 29.71 E 0,15 272,95 N 1~7,73 -2552,-80 ---22~2"80'-- 20 .... 0 ....... N 28.48 E ........... 0.92 .... $05.~1-'{~ ............. ~'75---E ...... 557.11 2~46.62 2556,62 20 50 N 28.50 E 0,50 555,85 N 181,26 E 370.91 25~0,13 2~50,15 20 59 N 28, 2 E C,51 56~_,05 N 198,02 E ~05,52 263~.60 2523'~60 20 ~0 ........ N 26.6~' E 0.55 ..... 59&.60 N .......... 2f~;35-'K ~0.~5 2727,~ 2617,~ 19 ~6 N 2&,6~ E 0,90 ~27,~9 N 229,8~ E 26~1,55 2711,55 19 ~5 N 25,52 E 0,06 ~57,72 N 2~,97 ,} . AMOCO PRODUCTION COMPANY .. 8M68 NUMBER -80 UT ~--~. iD DL-E1 R 0 U N D-FSH'O'A L ALASKA SPE.RY.,SUN WEL')SURVEYING COMPANY ~A-~Ci4%RAG'~ ~ 'A[XSkA COMPUTATION DATE ;AUGUST -13, .... 1975 DATE OF SURVEY AUGUST 10, 1975 SURWEL GYROSCOPIC MULTISHOT SURVI~Y KELLY BUSHING ELEV, '= I:LO.O0 FT. .:'TRUE ,SUB -SEA C OUR SE MEASURED VERTICAL V~'RTICAL INCLIt.~ATION ' DEPTH DEPTH DEPTH DEG ..... MIN ........ COURSE DOG-LEG DIRECTION SEVERITY DEGREES ............. DEG/i'O0 'TO RECTANGULAR ...... NORTH/SOUTH ..... TAL COORDINATES VERTICAL E'~-S'TT~'~'T- ......... SEC TI ON-' 5000 2915.83 :2805,83 19 12 N 27.16 E 31~-~--'3'01'0j19 -290'0;'1-9 I9 ...... 27'- "N"-25'*35'-'E' ~200 310~,82 .299~,82 18 15 N 22.61 E 3300 ~199,68 '~089,68 ~8 ~0 N 2~.65 E 3'~00 --329~";'57' 5I'8~'757--------~6 ...... 6-- N-20,'36-'E 3500 338~,,~3 ~279,33 19 10 N 21.~g E 3600 3~8~.97 ~72,97 21 52 N 2~,50 E 5700 ---$57~;~7 5800 ..566~,-52 555~,52 27 30 N 25,95 E ~900 375~'71 ~6~2.'71 28 ~ ': ~ 26.21 E .~OOO 58~0;~0 ..... $730;~-0 --2-~ 59 .... N-26,19"-E ~100 ~927,66 ~817,66 29 15 N 26.q0 E ~200 ~01~.87 ~90~,87 2~ 20 N 26.18 E __ ~30~-~10-2'~'02 --'5~92~02- 29~''-~ .... · ~00 ~188.85 ~078.85 30 5 N 26.~0 E ~500 ~275,~9 ~165.39 30 3 N 26,26 E 0,59 1.28 1.22 5~7.13 N 286,7~ E 0,~1 576.55 N 298,92 E 0';- 91 ........... 6 0'5-;"'6'~i ..... FT' ...... ~ ~87,~+7 N 260.02 E 5~0.35 .............. 517;'$9 N -27%~2~ ................572,~J8 1.11 655.53 N 321.89 E 2,77 667.92 N 555.25 E 2.9 6 ? 0 V,' 3i' N 3 5 ~-j~~' E 2.90 7~,36 N 369.38 E 1.2~ 786,68 FJ 390.09 E 0.25 -8-29."9~ 0.28 875,61 N ~32.96 0.14 917,~8 N ~5~.65 E 0.~8 1005.6~ a ~98.~ E ~.~9 1050,7~ N' 520,71 E 605.05 63 )~ 66't.~8-' 699,7A 73~.5~ 773',"~5 ..... 817,~ 865,85 911,3~ 95~ 22 1~0~.~0 ~153.69 5100 ~795 5200--~882 5~00 ~970 5~00 5056 5500 51~6 5600 5235 5700 5325 5800'---5~11 5900 5~98 6000 558~ .63 ~685.63 ;78'--q772j78 ........ .29 ~860.29 .05 ~9~6.05 jso --5o~6';5o ....... .06 5125.0~ ; 1 ~ -----5 3 O ~;I8'---- ~57 5388.57 ,03 5~76.03 3~ .....0 .... N 26'59 E .......... ~.'17 .... 50 0 N 26.21 E 0.19 29 56 N 26,81 E 0,31 29 .... ~0----N"26-',77 E 0.27 29 ~0 N 27.11 E 0,17 29 58 N 27,39 E 0 28--'~5 ..... N 27,50 E 1 2~ 8 N 26.58 E 0 26 10 N 28.97 E 27 .... 27 ...... N 29.99-E 27 5~ N 3~. 9 E 25 22 N 30.19 i -28'--30 ..... N"29,91 'E' 29 39 h 2~.93 E 28' 20 N 29,3~ E -'I095.55'~] ...... ~ .... 5'~-Ej9'8--~ ............. 12'0'2.91 11~0e3~ N 565.21 E 1252.09 1185,03 N 587.5i E 1301.21 ..... ieee ~0 '-N 60'~-,'91--~ ............ 135P 1273.52 N 63~.33 E 139 e33 1517.72 N 655.10 E 1~7.~1 .21 ..... 136t-;23 N .......... 6'77'"69-~ ..... 1%95.~6 .65 1%03.9% 0.98 1%%5.96-N 0.$6 ...... 1~86,57 0.~5 152&.78 6."7 1567,56 0.19 ....... 1601,-77 1,2% 1651.10 1.33 1693.~% 700.~% E 15W2.79 725,52 E 158~.56 769.72 g 1679,99 793,~0 E 1725,72 817.2~-E ......... 1771.52- 8~1.10 E 1619,19 66~,69 E 1866,~0 AMOCO PRODUCTION COMPANY .. SMGS NUMBER 9 ~~OUTH-M~DO~E--GROUND'$-HO-A-L ALASKA . . · SPERRY-SUN WEL. SURVEYING COMPANY ANCHORAGE, ALASKA DATE OF SURVEY AUGOST COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SUR¥~Y AUGUST"Z3,--~975 ............................... ~'O'~"-~'B'~R SU3-160~6 KELLY BUSHZN~ ELEV, = 110.00 FT, 'TRUE MEASURED VERTICAL DEPTH DEPTH SUB'SEA VERTICAL ~DEPTH COURSE COURSE INCLINATION DIRECTI '~IEG .... MZN ........... DESREE -. DCG-LEG TOTAL .- ON SEVERITY RECTANGULAR COORDINATES VERTICAL S .......... -D-EG]~!O-~I ..... NORTH/SOUTH ......... -~,-~T/WE~-'T ......... SECTIO~J .... 6100 .567q.0~ '6200 5762;'38' 6300 5850,82 6~00 6'500 6027,73 6600 6700 6205,86 '6800 -6295 6900 7000 '-7[0'0---- 7200 7300 7~00 7500 7600 ................... 7700 7800 7900 8000-- 8~00 8200 8500 ~00 8500 8600 .... 8700 8800 8900 9000 9100 656~ 6655 67~W 6931 7026 ...... 712i 72~7 7~[2 7~7 7502 75~7 7692 778~ 7881 797~ 8070 816~ .... 8258 8352 8~6 556~,0~ :57~0,82 582~,28 6006,~ 6095,88 · 2~ 627~,2~ ,50 6565,50 ;'o~ .... --:~ ,12 65~3.12 ;'86 ....~727-; 86 ,97 6821,97 ,63 6916,6~ .08 7[07,06 ,55 '7202,55 ;78 ..... 72~7;78 ,7~ 7392,79 ,~75 7~87,75 ,78 7676,7~ ,~2 7771,~2 ;13-" ,20 ,32 805~,32 ,99 82~2,99 ,76 8~6,76 28 22 N 29.q8 27 ...... 30 ......h $0,22 28 9 N 31.~5 27 26 N 30.86 26 39 N 50.50 E 0,09 1'7~.8~ N 888,00 E 1912,60 E 8,95 ......... i775;~''~ ..... ~Yi~-S'i--~ ............... 195~.o9 E 0,85 1815,53 N 955,20 E 2005-22 E 0,75 1855,~5 N 559,29 E 20~ ~ E ................ 0.75 ........... [ 895-;"5-~"'-~ ........ ~ ~--~-~--~ ................ 2093 ,'~ 5 .... K 1.53 1935.1~ N 100G,63 E 2157.91 26 '57 ......... 27 5 N ~1,9~ E '26 ~0 N 32,88 E 26 ....... 26 ...... N-2~,67 E 2~ 58 N 25.77 E 22 2~ N [5.50 E ;20 .... 30 ..... N 2.68 E 19 10 N 10,~ W 18 2~ N 15.77 0,60 0.66 0,62 0.72 3,65 1,57 ~.55 5,0~ 1,86 1973.50 [\I 1029.85 E 2181.16 2012.0~ N 1053,18 E 222~,67 2050,86 N 1076,7~ E 2268,99 2088.92 N 1100.89 E 2311.7~ '2'127'.92'N 1122.31 E 2555,L'~ .... 2167.17 i~ 11~0.79 E 25~7.S7 17 ..... ~9 ........ N 17,~2 17 0 N 21, 17 57 N 22,~8 17 ...... 55 ....;'-'N'25,81 18 26 N 27,81 18 7 N 29,11 l'~-'-23 ...... N 28,~9 19 20 N 27, 1~ 21 N 20,.3 19 ..... ~ ...... N 15,"9 20 ~5 N 16.18 18 57 N ~9 16 ..... N-"2.52 20 0 N 20' ~0 N ....... W ................ 0.80 ..... 23~5.'26'N W 1.55 2565,50 N 1152,85 £ 258q.q7 W 0,75 2591,13 N 1121,82 E 2607.97 ...... ....... W 0,81 2~6,79 W 0,51 2%7~,~6 N 108~.$E E 2676,50 W 0,~7 2551,85 N W 2,56 2561,5~ N W ......... 1,85 2591,86'N W 1,56 262~,51 N W 3,16 2657,~8 N -W 1'86 .......269d~-03' ~ ~ ~,86 ~72~,57 N ~ 1,06 '2758,~8 N 10~9,~9 E 2725,21 1036,36 E 2797,95 102~.61 E .... 277~.5~ 1017,~6 E 280~,~5 1010,26 E 2833,1~ 1007';~'~ 2865.59' 1005,55 £ 2695,51 1005.75 E .2925,22 '5 ' AMOCO PRODucTIoNs- COMPANY SMGS NUMBER 9 SOUTH-~ODEE--6~OUND--SHOAL ALASKA SPEF~RY-SUN WEL .~SURVEYIN_~ ":' ...... "-::~i~AN~'~'ORAGE ......................, ALASKA 'COMPUTATION DATE AU'GUST-15, .... 1975 COMPANY DATE OF SURVEY AUGUST SURWEL GYROSCOPIC MULTISHOT SURVEY ;JOB-'-NO' 8 R SU3- 6016 KELLY 5USHIN~ ELEV. = 1[O.O0 FT, -'TRUE :SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEPTH --DEPTH --'DEPTH DEG: .... MIN ..... COURSE DOG-L DIRECTION SEVERI DEGREES ..... ~EG~'[ E6 TOTAL TY RECTANGULAR COORDINATES VERTICAiL 00 ............. NOR TH/SOUTH ...... E-A-S-T/~E"ST .........SEC T 9SO' - SS3 ,-O'o .... 522'F0-0 9~00 872S,59 '8613,39 9500 '881~.'70 870~,70 .. 9600 8906,'31 ....... 8796;3'I" ' 97~0 899~.~6 6888.~6 9800 9090,96 8980.96 9900 10~00 10100 10200 10500 10400 9277,67 ~167,67 9571,07 '9261,07 9556°85 96~2 ~539~2 2[ 55 N ~,62 W '.23'"'-57---N .... 7.~5 W 2, 2~ 0 N 0,'79 W 2~ 7 N 1,&O W O, ZZ 50 ~ ~,49 ~ O, ~7 279~,5~ N 1002.09 E 2962,6Z 62 2873.78 N '9~5,5~ E 30~6.95 55 291~,5~ N 99~,65 E $07f "~' ~6 8993,~9 ~.j 990,5~ E ~50,75 -2~ 30 N 6, 6 W ~,~5 ~03~,15 N 987,08 E 3185,88 ;.2¢-~75~ ........ N ..... 9,'6~"~ ............. i°~Z ....... 20 ~l N 12,~8 W 1.03 ~101.79 N 975,$5 E 3250,55 . '21 Il N I~,52 W 0,82 ~136,5~ N 967,07 E' 3281.65 22 0 N 19.18 W 0.66 5207,52 N 9~5,28 E -22 2~ N 22,16 W 1,19 52~2,66 N 931,9~ E 5575,92 HORIZONTAL DISPLACEMENT:= 5575,92 FEET AT NORTH, 16 DEG, ,. -- 2 MIN, EAST AT MD = 10~00 THE C'ALCUE~TION'-PROCEOURES-ARE'-BASED-ON""'THE USE OF 'THREE--DINENSIONAL"'RADIUS OF CURVATU'RE-i~ETHCOo .~ ?-oyo ._. /,2. ~.~.o Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent September 19, 1975 File: GJR-785-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 5 , .,.. .. :,~ . ,.,.. ~ '. SMGS Unit Well No. 9 Attached herewith are the state of Alaska Forms P-4 furnishing monthly workover operations information for South Middle Ground Shoal Unit Well No. 5 and South Middle Ground Shoal Unit Well No. 9. Yours very truly, Geor.ge J. Ross Area Superintendent Attachments I~L'V. ~- I-?0 STATE ALASKA SUHMrr IN DU'~LIC,*,'~ OIL AND OAS CONSERVATION CONUVH~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WlI;LL WELL NAME OF OPERATOR Amoco Production Company ~, ADDR~-SS OF OPm~WOR P. O. Box 779, Anchorage, Alaska 99510 4 LOCA~ON OF W~-r-~- Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. APl NUMERICAL CODE 50-133-20086-01 LEASE DES:G~A'i~ON AN'D SERXAL NO ADL-18746 ~ IF TNDI^]4'. ^I-~itE~ OR TRIBE NAME SMGS Unit 9 WELL NO 9 Redrill ' i0" FIFJ~D ^_'qD POOL. OR V~'ILOCA?I' South Middle Ground Shoal 11 SEC . T.. R. M (BO"FTOM HOLE om,mc-'mv~ Section 35, T8N, R13W, S.M. llt PFL!R/VIIT NO 75-32 REPORT 'TOTAL DEPTH AT END OF MONTH, CHAA'GES IN HOLE SIZE, CA,.~ING AND CEMENT!NG JOBS INCLI,'DING DEPTH SET AND VOLLTIVfES USED. PEH~OHATIONS. 'rF_~TS A.bTD HESULTS FISHING JOB//; JL,'~K I.Nr HOI~E AND SIDE-T'~.ACKED HOLE A~N'D ~d~Y OTI~IBR SIGNIFICANT CHANGES IN HOLE CONDITIONS Summary 0,f Operations for August 1975: August 1-6: Directionally drilled and surveyed 9588-10,550'. Ran DIL-IES, Sonic and Density logs to 10,550' TD. August 7-11: Ran 83 joints of 7", 26# casing from 7000-10,550'. Cemented casing with 600 sacks Class G cement with 2% prehydrate gel and tailed in with 300 sacks Class G cement. Released from liner and circulated cement. Drilled out cement to 10,455' and tested liner to 1500 psi. Displaced hole with injection water. Ran gyro survey, Gamma Ray cement bond log and collar locator log. Dis- placed hole with power oil. August 12-13: Ran and set Baker F-1 packer at 9930'. Ran seal assembly, 2-1/2" Kobe Type "E" BHA and 3-1/2" tubing to 9905'. Ran dummy pump to gauge tubing. Pulled dummy pump and detected fluid influx. Reversed out power oil and water slug. Pressure tested to 2000 psi and bled back to 1400 psi in 15 minutes. Pulled Kobe BHA and stung into packer at 9930'. Pressured up tubing to 2500 psi and annulus to 1000 psi. Tubing pressure 2400 psi in 45 minutes and casing pressure 680 psi in 45 minutes. Pulled seal assembly and set 7" packer at 7060', pressured tubing to 2500 psi, held okay. Pressured annulus to 1100 psi and bled back to 800 psi in 10 minutes. Reset packer at 7028' and pressured tubing to. 3500 psi, held okay. Pressured casing to 1100 psi and bled off slowly. Pulled 7" packer and set 9-5/8" packer at 6990'. Pressured (continued) 14. I hereby ee~.~£y Mint the foregoingS. ~e and correct SIGNED /-3~tf~___a~.,, 0.~_'~ - ~Anc~ ~ Area Superintendent n~ _ September 19, 1975 NOTE--Re~ort on fbi. form is required for eOCh colendor ~nths regordless ~ the *to9us of ooerotlefls, end ~'~ filed In duplicate with the oil and gQs ~onservatbn commiflee bythe 15~ of the suecflding mon~. ufll,~ otharwis. ~irdcted, State of Alaska Form P-4 Amoco Production Company SMGS Unit Well No. 9 Redrill September 19, 1975 Page 2 (August 12-13) annulus to 1000 psi, held okay. Pressured tubing to 3500 psi and bled back to 2000 psi. Established injec- tion rate at 2-1/4 BPM at 3500 psi; 1-1/4 BPM at 3000 psi. Shut in tubing and pressure bled to 1950 psi in 15 minutes. Bled off tubing and casing and tubing flowed small stream. August 14-17: Pulled tubing, ran in with drillpipe and set 9-5/8" packer at 6828'. Established injection,' spotted 50 sacks Class G cement and squeezed to 4000 psi. Drilled out cement and pressure tested casing to 3000 psi for 30 minutes, held okay. Reran seal assembly, Kobe cavity, and 3-1/2" tubing. Displaced well with power oil and landed tubing. Nippled down BOP's and nippled up tree. August 18: Rigged up Dresser-Atlas and tagged bottom at 10,392'. Perforated the following intervals at 4SPF: 9,985- 9,990' 9,995-10,000' 10,078-10,083' 10,105-10,110' 10,123-10,128' 10,287-10,292' 10,309-10,314' 10,349-10,354' Ran standing valve and Kobe Type "E" pump TD 10,550' PBD .~. 24-hour test resUlts: ~' 2014 BOPD, 95 BWPD, 207 MCFD, 103 GOR. Final Report. l"orm No. P--4 REV. ~- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT 1~ DUPLICA'I~ OIL ~LL ___ NAME OF OP~I.A. TOR Amoco Production. Compan7 ADDRESS OF OP~gl~I. ATOR P. 0. Box 779~ Anchorage~ Alaska 4. LOCATION OF V~,~LL 99510 Leg 1, Slot 3, SMGS Platform Dillon, 743' FSL, 1818"FWL, Section 35, T8N, R13W, S.M. ~ AP! NU~{EmCAL bODE 50-133-20086-01 LEASE DESIGNATION AND SERIAL NO. ADL-18746 IF INDIA~. ALO'I i~:1~ OR TRIBE NAME 8, L,~IT FARAI OR LEASE NAJ~E SMGS Unit 9 WELL NO 9 Redrill 10 ~'LF.I,D AND POOL, OR WILDCAT .$ou~h Middle Ground Shoal SEC. T.. R., M. (BOTTOM HOL~ OBJ-F, CT~ Sec. 35, T8N, R13W, S.M. 12. P~'VIIT NO 75-32 "13. REPORT TOTAL DE~TH AT END OF MONTH, CHA~NGES IN HOLE SIZE, CASING AND C~WIENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ JL~K ~ HO~ AND SIDE-~CKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS Summary of Operations for July 1975: July 1-14: Directionally drilled and surveyed 8800-10,550'. Ran DIL, Sonic, Density and Dipmeter logs to 10,554'. Tripped in with bit and stuck pipe at 10,515'. July 15-18: Worked pipe, ran free-point and backed off at 9448' with free-point at 9488'. Proceeded to jar and work stuck pipe, ran free-point and backed off at 9293'. July 19-22: Tripped in with 8-1/2" wash pipe and washed over top five drill collars. Backed off at 9451' and recovered five drill collars. Tripped in with wash pipe and washed over fish from 9451-9626' Recovered five joints of drillpipe by backing off at 9666'. Washed over fish 9606-9726' but unable to recover any more pipe. July 23-25:' Screwed into fish, ran spud tool to 10,476', and perforated 10,473-10,475' at 4 SPF. Established circulation of 9 BPM at 1500 psi. Displaced 250 sacks Class G cement with 0.1 gallon per sack D-81 around fish. Backed off fish and circulated hole clean. After WOC, screw back into fish and pressured to 2900 psi and pressure held. Ran spud tool and top of the cement in the fish at 9611' and appeared fish was cemented. Spot 290 sacks Class G cement with 0.1 gallon per sack D-81, 0.23 gallon per sack D-80, 20% frac sand with slurry density of 17.1 ppg at the top of the fish. Pulled drillpipe to 9100' and circulated out trace of cement contaminated mud. (continued) 14. I hereby ce~ify %ha% the foreg°in~e and c~lTec% sx~mm ~ · ~- kfi~~" =~ Area Superintendent ~.~ Ausust 18, 1975 NOTE--Rego n this fo~ is required for eoch colendar ~nth% regQrdle~8 of the .totus 0f operottons, and must ~ filld i. dupli~te with the otl and gas conservatbn commiflee bythe 15~ of the succ~din9 mon~, ~leK 0therwis~ dirscted. State of Alaska Form No. P-4 Amoco Production Company SMGS Unit Well No. 9 Redrill Page 2 July 26-29: Drilled cement stringers 9110-9160' and hard cement 9190- 9200'. Tripped for dynadrill and kicked off at 9200'. Drilled to 9239' and unable to drill out of old hole. Run dynadrill and kicked off at 9336'. July 30-31: Directionally drilled and surveyed 9336-9588'. / ? ? ? G. J. Ross Area Superintendent August 18, 1975 File: G JR- 692-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 AUG 9 1975 Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 9 Attached herewith is the State of Alaska EormP-4 furnishing monthly workover operations information for South Middle Ground Shoal Unit Well No. 9. Yours very truly, George J. Ross Area Superintendent Attachments Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 G. J. Ross Area Superintendent July 16, 1975 File: GJR-603-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Monthly Report of Drilling and Workover Operations SMGS Unit Well No. 2~i'~'- ~: SMGS Unit Well No. 9 ~ ~J Attached herewith are the State of Alaska Forms P-4 furnishing monthly workover operations information for South Middle Ground Shoal Unit Well No. 2 and South Middle Ground Shoal Unit Well No. 9. Very truly yours, Supervisor in Charge Attachments l)ffl$10N OF OIL AND F~rm No. P--4 REV. 5- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT l:N DUPLICAT~ MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS WKLL 'WELL NAME OF OP~-ATOR Amoco Production Com~an~ ADS~SSO~O~ATO~ P. O. Box 779, Anchorage, Alaska, 99510 4 LOCA~ON OF WF. LL Leg 1, Slot 3, SMGS Platform "D", 743 FSL, 1818 FWL, Sec. 35, T8N, R13W, S.M. AP1 NTO%VIER1CAL CODE 50-133-20086-01 LEASE DESIGNA~ON AND S~IAL NO. ADL-18746 ~T IF INDIA)[ ALOT~EE OR TRIBE NAME 8. L,~IT FARA/I OR LEASE NAME SMGS Unit 9 WELL : 9-RD 10 F~ A_~D P~L. OR WILDCAT South Middle Ground Shoal SEC. T.. ~., O~rVF_.~ Sec. 35, T8N, R13W, S.M. 1~. PFJLMIT NO 75-32 REPORT TOTAL DEPTH AT END OF MONTH. CHA~'~GES IN HOLE SIZE, CASING AND CEMEN,'IqNG JOBS INCLI:D1NG DEPTH SET AND VOLLrMES USED, PER~O~TIONS, TESTS A1N'D RESULTS FISHING JOB~ JL~NK IN HOLE AND SIDE-TRACKED HOLE A~ND A.IWY OTHER SIGNIFICANT CHA~GES IN HOLE CON'DITIONS S-mmary of Operations for June 1975: June 6-11 Skidded rig, reversed out Kobe pump, cut the short string tubing at 10,190', and displaced the hole with salt water gell mud. Nippled down tree, nippled up BOPs and test to 2000 psi. Pulled and laid down short string tubing. Pulled long string out of packer and laid down tubing. Picked up 4-1/2" drillpipe and tripped into 10,258'. Circulated and set Model "~' retainer at 10,200'. June 12-15 Cement squeezed production perforations from 10,310-10,715' with 150 sacks Class "G" cement to 4000 psi. Perforated 7400-7401' with 4 SPF, set Baker Model "~' retainer at 7250' and squeezed 150 sacks Class "G" cement to 3500 psi. Perforated 7100-7101' with 4 SPF, set packer at 6800' and squeezed with 150 sacks Class "G" cement to 4000 psi. Ran in with bit and tagged cement at 6790'. Drilled out good hard cement to 7150' with no cement 7150-7250'. Ran in with mill and milled window 7134-7180'. June 16-18 Cleaned out to 7226', recovered coal and steel. Tripped in with open- ended drillpipe to 7224' and pumped 200 sacks Class "G" cement with 1% CaC1. Pulled up ten stands and reversed out 84 sacks of poor quality cement. Tripped out and waited on cement. Tripped in and drilled good hard cement 9658-7134'. Tripped out and tested BOP to 3000 psi and hydrill to 1500 psi. (continued) Supervisor S~GX~~/~3..~~L~/~~L~ ~upervisor in Char_ge ~A~ 7--16--75 ~Report on this fora is required ~r ea~ calendar ~ntht regardless of the status of operotio~S~ and must ~ filed Iff duplt~te with the oil and gas conssrvotbn commiflse bytho I~ of the suocNding mn~, ~le~ otherwise directed. Form No. P-4 State of Alaska Amoco Production Company SMGS Well No. 9 RD Page 2 June 19-30 Tripped in with dynadrill, oriented steering tool and kicked off at 7134'. Directionally drilled and surveyed 7134-8800'. (Survey details will be given on final report.) June 13, 1975 Re: South Middle Ground Shoal 9 RD Amoco Production Col~any 75-32 Mr. George J. Ross Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 35, Township 8 N., Range 13 W., S.M. Well sm~ples, core chips, and a mud tog, are not required. A directional survey is required. Pollution of any waters of the State is prohibited by As 46, Chapter 03, Article 7 and the regulations p?~ulgated t~reunder {Title 18, A. laska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amerind. Prior to commencing operations ~u may be contacted by a representative of the Depar~nt of Enviror~nental Co~ervation. In the event of suspension or~abandon~nt please give t~is office adequate. advance notification so that we may have a witness, present. OJ K. Gilbreth, Jr. Chai~n Alaska Oil and Gas Conservation C~ittee Enclosure cc: Depar~nt of Fish and GaR, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Department of Labor, Supervisor, Labor Lav.~ Compliance Di vi s ion w/o emcI. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 June 9, 1975 File: GJR-489-WF Mr. O. K. Gilbreth, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re: Application for Permit to Drill SMGS Unit Well No. 9 C. GEOL J C. ENG J , 1 ENG J 2 ENG J 3 ENO- 'J 4 EN® J 5 ENG J 2 G,-.OL J ....... 3 G~0L DRAFT J SEC J CONFER: FILE: Enclosed is an application for a permit to redrill South Middle Ground Shoal Unit Well No. 9. The proposed bottom hole location is 715' south- west of the present location. We plan to utilize 7100' of existing well in the redrill. Yours very truly, George J. Ross Area Superintendent Attachments DIV~ICN CF OIL AND GAS ANCHORAGE l%rm I0-- 4OI 1R~'V. i-l--71 lfL TYPJ Or WORK SUBMIT IN TRIP' IT~: (Other instructW,~ reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN .... DRILL [] b. TYPE OY WBLL DEEPEN .AP~ (J50-133-20086- O/ $. I~.,A~E DI~IGNATION A~D S~W~cL NO. ADL-18746 1. IF INDIAN. A.I.,I~T'I'E~ OR TRIBE NAME 8. UNIT FARM OR LEASE NA2VIE SMGS Unit 9. W~-LL NO. 9-RD 2. NAME OF opErATOR 81NGLm g MI'i,TII'I.J; r-] O?HmJ ZON{~ Amoco Production Company ... 3, ADDRESS P. O. Box 779, Anchorage, Alaska 99510 LOCATION OF WELL Atsurface Leg 1, Slot 3, SMGS Platform "D," 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M. At pro~sed prod. zone 1416' FNL, 2349' FEL, Section 35, T8N, R13W, S.M. 13. DISTANCE 1N MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE' 15-1/2 miles NNW of Kenai, Alaska 10. ~ELD AND POOL, OR WILDCAT South Middle Ground Shoal Il. SEC., T.. iR.. M,. i BOTTOM HOLE OBJECTIVE ~ Sec. 35, T8N, R13W, S.M. 12. 14. BOND INFORMATION: Statewide oil and gas bond - Division of Lands Bond File B-11 TYPE Surety a,d/o~ No. .. ,,_~o,~! $100, O00 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) .1275' FNL ADL-18746 18. DISTANCE FROM PROPOSED LOCATION* NO, OF ACR~ IN LEASE 4i60 9958' TVD 11. N(>. ACRES ASSIGNED TO THiS WELL 80 20. MOTARY OR CABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR. FI'. 11.35' S.~F~ Wall No. 8 Rotary 21. ELEVATIONS (Show whether DF. RT. C-R. etc.) 22.' APPROX. DATE WORK WILL START* RKB ]00' above MSL .... June 8,, 1975 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING. WEIGHT PER FOOT GRADE S~'TTING DEPTH q uantity of cement 26,, 20" ~85(J' ~ 94~/ ~&H 40 600' To surface .... 17-1/2" - 13-'3"/8" 54.5(/ J-55 2,.01.5.' To ~'~rface ,, ~2-1/4'.'.. 9-5./8" .... 40~/ '& 53..5(/ S-95 '&' i0.898' Previousl~ set -'proposed gi'nd.'.ow' .N-80 at 7122 ' 8.-1/2"., 7" .. "'2,..6i/ S-95 10,270' To k~¢k~off po.i'n,t in.,..9-5~.8." cas.i, nl DIV:SICI'< CF OIL AND GAS ANCHORAGE IN ABOVE SPACE D~:~.IBE I~OPosED PROGRAM: Ii ~W~I is to dee~n give ~ on p~sent p~u~lve zo~ ~d p~ ~w preclusive zone. if ~l is ~ ~r~ll or ~pen a~[o~lly, give ~ment ~' on s~bsu~a~ ~t~ ~d meas~d ~d ~ue 've~ical aep~. O, /e -bi~-u[ preventer- P~g~am, 24. I hereb~ certify that the Foregoin~ls True and Correc~ DAT~ June 9, 1975 ~ Area Superintendent (This space for State office use) SAMPLES AND CORE CHIPS RF~UII~.~ [] y~s ~ NO j DImCC'nO~A~ SUrVeY ~~ · ~ V~ 5 ~O CONDITIONS OF AJPP!RX)VA.L, IF AHY: MUD LOG U~ ~ ~o A.P.I. NUMERICAL CODE 50- ] 33-20086-0] ,,~,.~ ,o_ .J 5 - 3 2 _ , _ .%.PPlqOV~J.~ DAT~ · ~ Inmucflo., On Reverse Sid' June 13, 1975 · ,, Oun~ 1~; 1075 State of Alaska Form 10-401 Amoco Production Company SMGS Unit Well No~ 9 June 9, 1975 Page 2 Be 4, me e ® Planned Drilling Procedure Move on rig and remove existing downhole pumping equipment. Trip in with drillpipe with 9-5/8" c~sing scraper, displace hole with filtered seawater and clean to existing production packer (10,200'). Set cement retainer at 10,000' a~nd squeeze off existing perforations. Perforate at 7400' and squeeze to get cement behind pipe. Perforate at 7100' and block squeeze behind pipe. Mill a section from 7110' to 7170' and spot kick-off plug. Drill deviated hole to specified TD and location. Hang 7" liner to TD and cement. Recomplete as Lower Kenai Conglomerate (G zone). DIV!SION OF OIL AND GAS ANCHORAGE 54 ~5 · · I LEG. NO. ! LAT. G0~44' OS. IG" LONG. 151° 30' 4.5 85" Y = 2:463.917 FROM S.W. COR. 74~' I~ORTH 8 1818' EAST' 55 2 176'5' I SEWARC, MERIDIAN ALASKA · LEG NO. 2 LEG. NO. LAT. (;0044, 0772" LAT, 60~' 44' 07.C,,3" L[DNG. 151~ 30'44.7~" LON3 151o30'45.C--6'' Y = 2.463~,871 Y = 2.463~807 X = 229,319 X = 229,26:5 FROM' S.W. CC=~.' FROM S.W. COP. 699' NORTH & 633' NORTH 1872' EAST 1818' EAST I CERTIFICATE OF SURVEYOR ' 35 T8N 35 T 7 N SCALE' 1" /00'0' 2 Y = 2,46:5, 853 X = 2'29,211 FROM S.W. COP. 678' NORTH · 1765' EAST I hereby certify lhot !cm properly regislered ond licensed lo .proclice lend surveying in lhe Stole of Alosko or, d thai this ptot represents o locofion survey made by me or under my supervision end thc;l oll dimensions end olher del3ils ore correcl. Dole burve),or ~ .. 3G 36 LEG. NO. 4' LON$.ISI° 30' 4594" ~ (2/ SURVEYORS NOTE " · . · The Iocolion of S.M.G.S. Platform "D" wos accomplished ,. . . "Co 1" " by us,' of U.S.C. ~, G S slolions s , Easl Fore.snJ I i n h ! '~ " " FINAL PLAT OF S.M.G.S. PLATFORM "D" LOCATED IN 5UhVE¥;,.O · PAN AMERICAN PO. BOX 779 AI'~ C~IO q :,C, F., SURV~YFb " E M. LIN.r)sEY & ASS.S",'.,. ' · o N~ . .. . . _ o. ' - R. 13 W. - A,.,.,~ R ! C/',I',~-- PAN /? ~,,~, ~ D ' · ~4PL /~7750 ~' , . . . . . . . .. ~ ~L 1~7~ ~ · . .' ...' ~ · . .. ~ ~ . PAN AMERICAN- 3KEL_LY SINCLAIR- PH t_LIPS , R. 13W. ADL 18744 ADL 18746 AD[. I8750 Federol Icc, sos 0 Ac. $1ote looses 41GO Ac,:_': Total 4160 Acres o --L~GEND- .-.r=~=~=~U~i'F BOUNDARY TRACT BOUNDARY TRACT NUMF3ER . o ' Chock Vg, ive Spool -2" Plug Valve on ida out l'e t Jipmenn below nhis ~ i ." ~n~ished by Pan Am. -~----P ipe Rar. s plug V~iVe 4"' line w/$hcp ma(ia s:;:ge') ::/no ""~' .. bend !~-~---2" plug valve "' ~ 2" l~ne .choke J 1 .. Ail prevcntor's Co. be hydrauiica~iy operated from ar, accur::ala or x~nlch will open' close ~ ' '' ,,z.t;,ou- recharging " ,.ybr~: az feast three :lines"'"" ~ . All equii)r:ent thru which bit must pass to have at least as large iD as casing being drilibd through. '. . Keil~ cock to be.on lle!iy iron t~ne of spu~. Drill.oi:2a s;:,fety va;v~' ' equivalent to Sa,.ffe~' ~ Mod, 55 or OMSCO, with pro?e" connections, to be.on rig floor at ail ~ines. · . ,. ,,~"' ! cquion'~ent mentioned above to be 5000<-: W? or stronger. Ail co::nections to be fla,;ged. · o · ' - ' .e,,~., rfiiars station w/2 re;',~occ opo.,, "i ..... O:,e~arJ. ng ;.nan~fold ooe in easy .... "of 'd " station.. · ... , , LEO. NO.I LAT. 60~44' 0~.1,5" LONG. 151' 30' 4,5 Y = . X = 229,266 FROM 5. W. COR. 74~' NORTH 8 1818' EAST oe...,,..Z,,_ - . - I ' ' i 55 .J"~j ' Ii T 8 N ' 2 SE',VARJ ,MERIDIAN ALASKA T 7 N ~5 SCALE ' I"'1'000' 2 36 LEG NO. 2 LEG. NO. 3 LAT 60°44' 0772" LAT. 60~ 44' 07.C.,,3" L~NG. I51° 30'44.78" LON5 151° Y = 2,463,871 Y = 2,~6~,807 K = 229,519 X = 229~265 FROM' S.W. COq.' FROM S.W CO~. G99' NORTH & 6~' NORTH 1872' EAST 1818' EAST LEG. NO. 4' LON$. 151° :30' 45 Y = 2,465, 853, X = 229,211 FROM S.W'. COR. 678' NORTH · 1765' EAST CERTIFICATE OF SURVEYOR ' I hereby cerlify thot I om properly regislered' and licensed fo .proctice lond surveying in the Slote of Alosko or, d thol this plo! represents o location survey mode by me or under my Supervision and Ih(il oll dimensions ond olher del3ils ore correcl. Dote ::,ur veyor o SURVEYORS NOI'F_ l'he Iocotion of S.M.G.S. Plotform "D" wes eccompl;shed II II by use of U.S.C. 8, G.S. stolions "Cosl , kasl Fore.snd FINAL PLAT OF PAN A;.1ERICAN F'F_.TRO/r~''' r"":" PO. COX 779 /,,NCt. iOr~:,Gr- ,~, :.c,(:. SURVEY['D 5Y ' E M. LINDSEY & ASS:'(.. 8 NI . '- N. o . o "n I":1 r.'-J =:, v=, r.-.'~ n 27' PAN AMERICAN-- SKELLY-SINCLAIR- PI41L_I_IPS ,4DL /8750 PAN AMERICAN- SINCLAIR- PI-I .ADL 18744 ADL 18746 ADL 18750 FodeFoI leoses Slate leases 'fo ! al 0 AC:. 4160 Ac.. Acre s · R. 13 W, o 8 · o .T. , · u r.~ [--' *'-'n ~ UI~ IT BOUNDARY TRACT BOUNDARY · TRACT NUMBER · . · , · EXHIBIT ",-, ^'' TO ACCOMPANY "~ · /?, "' "'~'; ', t O:..'" : SO' '°:"" r,,':,,.,:), :: ;-<L)~., D ,.~..~, d'-.l.. Uit'i i,.i ~. ..... ~, ,- /'~, I.' '.~:" .4 :' .: ..~ UNIT ,-,,.,,, ........,. · COOK INLEI' BASIN, ALASXA O I/2 I ' 2 J..=:_~?.~==: ........ .___,. .............. =,:=::.:=.- !' Chock Valve ._<----Pipe Rams .............. : .... : ....... ..-....---.. ~ '. " -' i "' Or 4" i~gate va lye / 2"Piu Valve Plug or Gale .Valve 4" plug, vgive 4" line w/":' · made s:;:".ep ',:/no / t'..~nre. %h.:.n !:5c band 2" Plug Vt.:v~ on ;ida outYet nipr, ent below chis ~n%ighed by Pan · . · All prevcntor's Co b~ hydraui~ .... ., zrom an accur::dlator which %e~ 11 open and . close hydz'il an i'e'ast three times '~:'ithoua recharging. " , , . All equipn~ent thru which bit muSg pas:; to have at least as large iD as casing -. dr,.ziad ~h~-o6gh , Kelly cock :o be on l-:a!lY from time of spud. = . ..... with pro?er connections . . va=v= equ~valen; to Shaf~er }~od 55 or O:,$uO, , Drill oi:~a slfety ' ' ' ' to be on ri', floor at ail J____~ .-~---- .-o----- }:ud Cau',e . plug . .,,~ ' / l; 0 ',~ ~~ piu~ valve 2" Iine .choke ~.~?. · ,~, equior.'=ent r, entionad above to be 5000(..= W? or stronger. · All co:;nec="o;',:~ to be fla,;ged. ' · '. Ope-~zc:"", ;.~anifold co be in easy reach oJ drillers station ~,'/2 toluene opara::in$ station .- . · · . . ... . CHECK LIST FOR NEW WELL PERMITS Company /~~)0_.~) Lease & Well No. ~, /~/~S {~7z ~x~'~ Yes No Remarks 1. Is the~ permit fee ~.tta.ched ...................... , .__~ /~Sc~~ , , , 2. Is well to be located in a defined, pool ............... ~t: 3. Is a registered survey P!._a.~.~' -'tached ................ 4. Is ~ell located proper distance from property line .......... ~a~ 5. Is well located proper distance from other wells ........... /~ 6. Is sufficient undedicated acreage available in this pool ....... ~ 7. Is well to be deviated., ....................... /~ .... 8. Is operator the only affected party ................. 9. Can permit be approved before ten-day wait ............. ,, 10. Does operator have a bond in force · .- ............... ~a~ I I. Is a conservation order needed ..................... ~ 12. Is administrative approval needed .................. ~q 13. Is conductor string provided ................ · . . . 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings . 16. Will cement cover all known productive horizons .. ......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst . .,~ ... 19. Does BOPE have sufficient pressure rating ~ Additional Requirements' Approval Recommended' Geology ~ Engineering: TRM ~ HWK OKG HHH JAL . LCS"~'~., JCM Revised 1/15/75